Source: http://www.pabulletin.com/secure/data/vol41/41-6/239.html
Timestamp: 2015-04-28 11:50:39
Document Index: 659445820

Matched Legal Cases: ['§\u2002601', '§\u2002510', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200267', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u2002601', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u200213101', '§\u2002745', '§\u2002745', '§\u200278', '§\u200278', '§\u200278', '§\u200278', '§\u2002601', '§\u2002721', '§\u2002601', '§\u200278', '§\u2002601', '§\u200278', '§\u200291', '§\u2002691', '§\u20026018', '§\u200278']

PA Bulletin, Doc. No. 11-239
[41 Pa.B. 805][Saturday, February 5, 2011]
The Environmental Quality Board (Board) amends Chapter 78 (relating to oil and gas wells) to read as set forth in Annex A.
Properly constructed and operated oil and gas wells are critical to protecting water supplies and public safety. If a well is not properly cased and cemented, natural gas in subsurface formations may potentially migrate from the wellbore through bedrock and soil. This stray gas may adversely affect water supplies, as well as accumulate in or adjacent to structures such as residences and water wells. Under certain conditions, stray gas has the potential to cause a fire or explosion. These situations present a serious threat to public health and safety as well as the environment. The purpose of this final-form rulemaking is to improve drilling, casing, cement, testing, monitoring and plugging requirements for oil and gas wells to minimize gas migration and protect water supplies.
The final-form rulemaking differs from the proposed rulemaking in several important respects. The differences reflect the concerns raised by the regulated community and the public, resulting in improved regulations. The changes to the final-form rulemaking strengthen well design requirements to prevent gas migration incidents.
The significant revisions to the final-form rulemaking include the following: the addition of a provision that requires operators to have a pressure barriers plan to minimize well control events; the addition of a provision that requires operators to keep a list of emergency contact phone numbers at the well site; amended provisions that clarify how and when blow-out prevention equipment is to be installed and operated; the addition of a provision that requires operators to condition the wellbore to ensure an adequate bond between the cement, casing and the formation; the addition of provisions that require the use of centralizers to ensure that casings are properly positioned in the wellbore; the addition of a provision that improves the quality of the cement placed in the casing that protects fresh groundwater; the addition of provisions that specify the actions an operator shall take in the event of a gas migration incident; and revisions to the reporting requirements for chemicals used to hydraulically fracture a well.
This order was adopted by the Board at its meeting of October 12, 2010.
For further information, contact Scott R. Perry, Director, Bureau of Oil and Gas Management, Rachel Carson State Office Building, 5th Floor, P. O. Box 8765, Harrisburg, PA 17105-8461, (717) 772-2199; or Elizabeth A. Nolan, Assistant Counsel, Bureau of Regulatory Counsel, Rachel Carson State Office Building, 9th Floor, P. O. Box 8464, Harrisburg, PA 17105-8464, (717) 787-7060. Persons with a disability may use the Pennsylvania AT&T Relay Service, (800) 654-5984 (TDD users) or (800) 654-5988 (voice users). This final-form rulemaking is available on the Department of Environmental Protection's (Department) web site at http://www.depweb.state.pa.us.
The final-form rulemaking is being made under the authority of section 604 of the Oil and Gas Act (act) (58 P. S. § 601.604), which directs the Board to adopt regulations necessary to implement the act, and sections 1917-A and 1920-A of The Administrative Code of 1929 (71 P. S. §§ 510-17 and 510-20). Section 1917-A of The Administrative Code of 1929 authorizes and requires the Department to protect the people of this Commonwealth from unsanitary conditions and other nuisances, including any condition that is declared to be a nuisance by any law administered by the Department. Section 1920-A of The Administrative Code of 1929 authorizes the Board to promulgate regulations of the Department.
D. Background of the Amendments
The proposed rulemaking was published at 40 Pa.B. 3845 (July 10, 2010). The public comment period closed on August 9, 2010. In addition, five public hearings were held: July 19, 2010, in Tunkhannock, PA; July 21, 2010, in Williamsport, PA; July 22, 2010, in Meadville, PA; July 22, 2010, in Pittsburgh, PA; and July 26, 2010, in Pittsburgh, PA.
Prior to recommending that the proposed regulations be offered to the Board, the Oil and Gas Technical Advisory Board (TAB) formed a technical subcommittee with representatives from various companies, trade groups and consultants to review and provide comments on the proposed rulemaking. The Department met with TAB and the technical subcommittee on October 28, 2009, January 14, 2010, January 21, 2010 and March 25, 2010.
The Department presented the draft final-form rulemaking to the TAB on September 16, 2010. During this discussion, TAB members made several recommendations regarding the definition of ''unconventional formations,'' use of blow-out preventers, cementing the intermediate casing, producing gas off the intermediate casing and the actions the operator shall take when it loses circulation of cement. At the conclusion of the meeting, TAB members were neither able to endorse nor disapprove the rulemaking and instead expressed an interest in having the TAB subcommittee review the amendments to the final-form rulemaking.
The Board received approximately 2,000 comments regarding the proposed oil and gas well casing and cementing regulations during the public hearings and public comment period. Many of the comments received sought clarification or additional protective measures. The majority of comments were supportive of the proposed rulemaking.
Several commentators made suggestions seeking to clarify the definition of ''deepest fresh groundwater,'' including suggesting that the term be defined with reference to certain levels of total dissolved solids (TDS) ranging from 500 to 10,000 mg/l TDS. The Board appreciated these comments, but decided that numerical criteria should not be used to define deepest fresh groundwater because many water supplies provide water that exceed the 500 mg/l drinking water standard, but 10,000 mg/l is far too saline for drinking water supplies in this Commonwealth. It is critical that the casing be set deep enough to isolate usable water supplies but not so deep that brine be permitted to comingle with fresh groundwater. It is also important to recognize that testing water produced during drilling will not yield accurate test results. For these reasons, the final-form rulemaking has been amended to require operators to identify how the deepest fresh groundwater was determined and record the information in the casing and cementing plan.
Many commentators sought clarification regarding the provisions that require an operator who affects a water supply to restore or replace the affected water supply with an alternate supply adequate in quantity and quality for the purposes served by the supply. The amendments to § 78.51 (relating to protection of water supplies) reflect the Department's interpretation of an adequate alternate water supply according to recent case law.
Several commentators suggest that all replaced or restored water should meet safe drinking water standards. The Board deems a supply adequate if it meets safe drinking water standards or is comparable to the unaffected water supply if that water supply didn't meet those standards.
A commentator was uncertain about who would determine reasonable foreseeable uses. The regulation states that it is the duty of the Department to determine if the operator is in compliance with this subsection.
Additionally, several commentators were concerned that § 78.51(h) did not provide a timely response for affected water supplies. The Board agrees and amends § 78.51(h) to require operators to notify the Department within 24 hours of receiving a report that a water supply has been affected by pollution or diminution caused by drilling activities.
Several commentators objected to the provisions that would allow the use of used pipe. The Board considers used casing to be acceptable in certain applications, notably in low pressured shallow oil wells that do not produce gas. In these instances, used casing has been utilized successfully and has been shown to be suitable for long-term use in these applications. All used casing, however, is subject to the casing integrity requirement in § 78.84(b) (relating to casing standards), as well as new requirements for pressure testing in § 78.84(c).
Many commentators suggested amendments to § 78.85(b) (relating to cement standards) that would require a 72-hour compressive strength standard of at least 1,200 psi across critical zones of cement at the bottom of the casing seat where the highest pressures and stresses are likely to be encountered and in places where the well bore passes through aquifers and drinking water. The Board agrees and amended § 78.85(b) to require a zone of critical cement at the surface casing seat which must achieve a 72-hour compressive strength of 1,200 psi and have a free-water separation of no more than 6 milliliters per 250 milliliters of cement.
Several commentators suggest that the cement ticket include testing of pH, temperature and a record of the wait on cement time. The Board agrees and the regulation has been revised accordingly.
Some commentators objected to the quarterly mechanical integrity inspections required under § 78.88(a) (relating to mechanical integrity of operating wells), arguing that the requirement is excessive. While several commentators believed that quarterly inspections were not enough, other commentators supported the quarterly inspection requirements in § 78.88(a). The Board decided that quarterly inspections are sufficient to ensure that well pressures are within allowable limits and the casing is structurally sound. The Board does not consider quarterly mechanical integrity testing to be excessive. Rather, the inspections provide the operator an opportunity to correct problems at the well before the problems create a condition that will require significant time and expense to address. The Board also determined that required evaluation of the well does not include invasive procedures.
Several commentators made suggestions to § 78.89 (relating to gas migration response), regarding gas migration response requirements, including a provision requiring immediate notification to the Department. The Board agrees and amended the final-form rulemaking to require the operator to immediately conduct an investigation and contact the Department.
Commentators suggested that operators conduct an initial response action to determine the nature of the incident, assess the potential for hazards to public health and safety and mitigate any hazard posed by the concentration of stray natural gas in the environment. Commentators suggested that the investigation include a site visit and an interview of the complainant. Commentators suggested that the actions that an operator shall take in the event of a reported gas migration incident be delineated by the concentration of combustible gas detected in the investigation. Commentators also suggested other additional investigation and mitigation measures that operators should be required to take, including a field survey, the collection of gas or water, or both, samples, the establishment of monitoring locations, and an evaluation of the operator's adjacent wells. Commentators also suggested certain reporting requirements following a reported gas migration incident. The Board agrees with many of the commentators suggestions and revised § 78.89. These changes largely follow the commentators' suggestions. The revisions also require continued monitoring of gas migration complaints when the levels of dissolved methane in the water supply exceed 7 milligrams per liter. This level is based on 25% of the capacity of water to contain dissolved methane under one atmosphere of pressure. This number is much more certain and scientifically based than the unknown ''background'' level proposed by the commentator.
Commentators suggested that the information required in the completion report's stimulation record be expanded to require more specific information, including information regarding the chemical additives used and the chemicals listed in the operator's Material Safety Data Sheets by Chemical Abstract Number. Other commentators object to requirements that require operators to submit confidential information and suggest that the issue of confidentiality be addressed in § 78.122 (relating to well record and completion report). The Board expanded the stimulation record requirements in § 78.122(b)(6) to include the Chemical Abstract Number for each Material Safety Data Sheet-listed hydraulic fracturing chemical used, as well as the percent (by volume) of each listed chemical used. The Board also amended this subsection allowing the designation of confidential or trade secret information. The Department will prevent disclosure of the designated confidential information to the extent permitted under the Right-to-Know Law (65 P. S. §§ 67.101—67.3103).
F. Summary of Final Form Regulation and Changes from Proposed to Final Form Rulemaking
Section 78.1 amends the definitions of the following terms to improve clarity or to explain new or existing provisions: ''casing seat,'' ''cement'' and ''surface casing.'' Section 78.1 also adds definitions for the following terms to explain new or existing provisions within Chapter 78: ''cement job log,'' ''conductor pipe'' and ''intermediate casing.''
The final-form rulemaking amends the following definitions in response to public comment to improve clarity: ''casing seat,'' ''cement job log,'' ''intermediate casing'' and ''surface casing.''
The definition of the term ''retrievable'' has been deleted. The substantive portion of the term has been added to the appropriate plugging regulations.
Definitions for ''L.E.L'' and ''unconventional formations'' have also been added to § 78.1.
§ 78.51. Protection of water supplies
The act requires an operator who affects a water supply by pollution or diminution as a result of gas or oil well drilling to restore or replace the affected water supply. Section 78.51 reflects current case law regarding an operator's duty to replace or restore a water supply.
Section 78.51(d)(2) provides that a restored or replaced water supply must meet safe drinking water standards. If the precontamination water supply did not meet safe drinking water standards, the operator shall restore or replace the contaminated water supply with a supply that is comparable to the water supply that existed prior to contamination.
Section 78.51(d)(1)(v) requires the operator to provide permanent payment for any increased cost to operate or maintain the restored or replaced water supply. Section 78.51(d)(3)(i) and (ii) clarifies that the replaced or restored water supply must be able to satisfy the water user's needs.
The final-form rulemaking modifies proposed § 78.51(d) to provide uniform terms and add clarity and amends § 78.51(h) in response to public comment, providing that an operator who receives notice that a water supply has been affected by pollution or diminution shall notify the Department within 24 hours of receiving that notice.
§ 78.52. Predrilling or prealteration survey
Section 78.52(d) provides that an operator shall provide the Department and the landowner or water purveyor with the results of their predrilling survey within 10 business days of receiving the survey results. The final-form rulemaking establishes that survey results not received within 10 days may not be used to preserve the operator's defenses under section 208(d)(1) of the act (58 P. S. § 601.208(d)(1)).
§ 78.55. Control and disposal plan
Final-form § 78.55(b) establishes that an operator's control and disposal plan must include a pressure barrier policy identifying the pressure barriers to be used during identified well drilling and completion operations. Final-form § 78.55(e) provides that an operator's control and disposal plan must also contain a list of emergency contact phone numbers and that this list shall also be displayed at the well site.
Final-form § 78.55(d) establishes that an operator's control and disposal plan shall be available at the well site during well drilling and completion operations.
§ 78.71. Use of safety devices—well casing
Section 78.71(a) clarifies that the well control equipment must be attached to casing that is cemented in place.
Final-form § 78.72(a) clarifies when blow-out equipment shall be used. The final-form rulemaking specifies that blow-out equipment shall be used when drilling a well intending to produce from an unconventional formation and when drilling out solid core hydraulic fracturing plugs to complete a well.
Section 78.72(c) establishes that controls for the blow-out preventer shall be accessible in case of an emergency. Final-form § 78.72(c) specifies that controls for a blow-out preventer with a high pressure rating must be located at least 50 feet away from the drilling rig to assure accessibility in the event of loss of well control.
Section 78.72(f) is amended to clarify when drilling shall cease when blow-out prevention equipment is discovered to be in poor working order.
Final-form § 78.72(h) establishes that an individual with specified certifications shall be at the well site when blow-out prevention equipment is being used and that those certifications shall be available at the well site.
The final-form rulemaking adds § 78.72(i) to establish that pressure barriers must be comprised of at least two mechanical pressure barriers between the open producing formation and the atmosphere. Additionally, these mechanical pressure barriers must be capable of being tested according to the manufacturers' specifications prior to operation. Moreover, if the operator has only one pressure barrier, operations shall cease until additional pressure barriers are added or repaired and tested.
Final-form § 78.72(j) establishes that a hydraulic workover unit shall be used during postcompletion cleanout operations in unconventional formations.
The final-form rulemaking specifies that intermediate casing must be cemented to surface, and now allows blow-out preventers to be attached to surface casing without regard to its length.
§ 78.73. General provision for well construction and operation
Section 78.73(a) and (b) further clarifies that the well shall be constructed and operated in a manner that protects public health and safety and the environment.
Final-form § 78.73(c) reduces the allowable pressure that may be exerted on the surface and coal protective casing seats. The final-form rulemaking clarifies how to calculate the pressure that must not be exceeded on the surface and coal protective casings. The final-form rulemaking specifies that the pressure on the surface or coal protective casing seats is determined by measuring the surface shut-in pressure and the surface producing back pressure exerted on the surface or coal protective casing.
Section 78.73(e) is added to require excess gas encountered during drilling to be flared, captured or diverted away from the drilling rig. Section 78.73(f) is added to require check flow valves that prevent backflow from the pipelines into the well.
§ 78.75a. Area of alternative methods
The act provides that the Department may approve alternative methods for the casing, plugging or equipping of a well. New § 78.75a establishes procedures by which the Department may on its own initiative designate an area of alternative methods—an area that requires alternative drilling, casing, equipping or plugging methods to operate the well in a safe and environmentally protective manner. Establishing an area requires notice in the Pennsylvania Bulletin and an opportunity for the public to comment.
§ 78.81. General provisions
Section 78.81(c), which stated that certain sections of the chapter did not apply to production or intermediate casings, is deleted to reflect new casing requirements.
§ 78.82. Use of conductor pipe
Final-form § 78.82 clarifies that conductor pipe is used to stabilize the top hole of a well and shall be driven into place or cemented from the seat to the surface to prevent the infiltration of water or other fluids into the subsurface.
§ 78.83. Surface and coal protective casing and cementing procedures
Section 78.83(a) prohibits the use of surface casing as production casing and requires an additional string of casing to be installed in a well unless the well is only used to produce oil that does not present a threat to groundwater or if the operator of a gas well demonstrates that all gas and fluids will be contained in the well and installs a working pressure gauge that can be inspected by the Department.
The final-form rulemaking deletes § 78.83(c), which gave operators the ability to drill to producing zones prior to isolating the fresh groundwater under certain circumstances, and adds new § 78.83(c) to require the use of air or freshwater based fluids when drilling through the fresh groundwater zone. Additionally, final-form § 78.83(c) specifies that the surface casing must be set 50 feet below the deepest fresh groundwater or at least 50 feet into consolidated rock, but not more than 200 feet below the deepest fresh groundwater unless necessary to set the casing in consolidated rock. The final-form rulemaking also establishes that the wellbore shall be conditioned prior to cementing.
The final-form rulemaking amends § 78.83(c), (f), (g) and (i) to mandate the use of centralizers to position the surface casing, coal protective casing and any additional fresh groundwater casings in the wellbore. Subsections (f) and (i) have been further amended to require the additional water string to be cemented to the surface as opposed to 20 feet into the surface or coal protective casing.
§ 78.83a. Casing and cementing plan
Section 78.83a establishes that operators shall develop a casing and cementing plan that is available for the Department to review at the well site. The plan must describe the casing to be used and the cementing practices to be employed. The Department may request a copy of the plan for review and approval prior to drilling.
The final-form rulemaking amends § 78.83a(a)(1) and (6) to specify that the operator shall include in its casing and cementing plan the method or information by which the depth of the deepest fresh groundwater was determined and the proposed wellbore conditioning procedures.
§ 78.83b. Casing and cementing—lost circulation
Section 78.83b(a), added on proposed rulemaking, requires operators to notify the Department when cement used to protect fresh groundwater is not returned to the surface despite pumping more than 120% of the estimated required volume. If cement is not returned to the surface, the operator shall determine the top of the cement and additional casing must be run and cemented, unless the well only produces oil off a vented production pipe if approved by the Department. Final-form § 78.83b(a)(1) clarifies what the operator shall do when this happens and what additional measures must be taken.
The final-form rulemaking adds § 78.83b(b) to provide that, in the event of lost circulation, the operator may, in addition to the requirements in § 78.83a(a), pump additional cement through a pour string from the surface to fill the annular space.
§ 78.83c. Intermediate and production casing
Section 78.83c, added on proposed rulemaking, specifies the cementing requirements for intermediate and production casing and establishes the pressure limitation for wells that produce gas off the annulus of the intermediate casing string.
The final-form rulemaking adds new § 78.83c(a) to require the intermediate and production borehole to be prepared prior to cementing. The final-form rulemaking amends § 78.83c(b) to mandate the use of centralizers when cementing the intermediate casing and requires the intermediate casing to be cemented to the surface.
The final-form rulemaking amends § 78.83c(c) to mandate the use of centralizers when cementing the production casing and further specifies how much cement must be used to cement production casing.
§ 78.84. Casing standards
The substantial amendments to § 78.84 require specified pressure ratings or pressure testing for different types of casings. Final-form § 78.84(d)(3) clarifies the certification requirements for a person welding casing.
Final-form § 78.84(f) clarifies that if the casing attached to the blow-out preventer has a pressure rating of greater than 3,000 psi, it shall be pressure tested after it is cemented. To pass this pressure test, the casing must be able to hold the anticipated maximum pressure to which the casing will be exposed for 30 minutes with not more than a 10% decrease.
§ 78.85. Cement standards
Section 78.85 provides additional standards for well casing cement, as well as references to ASTM International and American Petroleum Institute standards.
The final-form rulemaking amends § 78.85(a)(4) and deletes proposed § 78.85(a)(5), clarifying that cement must protect the casing from corrosion and degradation, including that the cement used for coal protective casing must be formulated to withstand elevated sulfate concentrations in the surrounding wellbore. New § 78.85(a)(5) specifies that gas block additives and low fluid loss slurries shall be used in areas of known shallow gas producing zones.
The final-form rulemaking amends § 78.85(b) by adding requirements regarding surface casing cement. This subsection specifies that the cement at the bottom 300 feet of the surface casing constitutes a zone of critical cement, meaning that the cement in this zone must achieve a 72-hour compressive strength of 1,200 psi and the free water separation must not be more than 6 milliliters per 250 milliliters of cement.
The final-form rulemaking amends § 78.85(c) by clarifying the actions that are prohibited during the mandatory 8-hour wait time on the cement for all casings.
Final-form § 78.85(f) specifies the information that must be included in the operator's cement job log.
§ 78.88. Mechanical integrity of operating wells
Section 78.88, added on proposed rulemaking, requires operators to inspect their wells at least quarterly for signs of physical degradation in addition to determining whether the pressure in the well is within allowable limits. Wells that fail inspection shall be attended to immediately and the Department shall be notified.
§ 78.89. Gas migration response
Section 78.89 is substantially amended in the final-form rulemaking to specify the actions an operator shall take in the event of a gas migration incident. Final-form § 78.89(a) requires an operator to conduct an investigation immediately after it is notified or otherwise made aware of a potential gas migration incident to assess the nature of the incident, assess any potential hazards and mitigate any hazards. Final-form § 78.89(b) specifies that the investigation shall consist of a site visit, an interview of the complainant, a field survey and, if necessary, monitoring locations shall be established. If the operator detects a high concentration of combustible gas inside a building or structure, final-form § 78.89(c) establishes that the operator shall immediately notify the Department and local emergency response agencies, initiate mitigation measures and conduct further investigation and monitoring of the surrounding area.
Final-form § 78.89(d) specifies that if sustained detectable concentrations of combustible gas are detected at certain specified levels, the operator shall notify the Department and take measures to ensure public health and safety. If the operator conducts an investigation and is not required to take the measures specified in § 78.89(c) or (d), § 78.89(f) requires the operator to conduct additional monitoring, document its findings and submit a report.
The final-form rulemaking adds § 78.89(e) to establish that the Department may require the operator to take additional investigative and monitoring measures in the event of a reported natural gas migration incident. Final-form § 78.89(g)—(i) provides additional notification and reporting requirements.
§§ 78.92—78.95
Sections 78.92—78.95 incorporate the substantive requirements of the deleted definition of ''retrievable'' along with requiring an additional attempt to remove uncemented casing prior to plugging a well. The revised sections also require cement to be placed across the formerly producing formation as opposed to placing the cement plug on top of the formation as is the current requirement.
§ 78.96. Marking the location of a plugged well
Section 78.96(a) permits the use of materials other than cement and metal to mark and hold a marker for a plugged well.
Section 78.121 incorporates the requirements of the act of March 22, 2010 (P. L. 169, No. 15) (Act 15), which mandates semiannual production reporting of Marcellus Shale wells. In § 78.121(a), the dates are amended to reflect the requirements in Act 15. Because Act 15 also requires the Department to post the production of Marcellus Shale wells on the Department's web site, § 78.121(b) is amended to require that the production reports be submitted electronically.
§ 78.122. Well record and completion report
Section 78.122(a)(10) requires the operator to certify that the well has been properly constructed. The final-form rulemaking amends § 78.122(b)(6) to require the operator to submit additional information in its completion report's stimulation record, including a descriptive list of the chemical additives used in the stimulation fluid, the percent by volume of those chemical additives, a list of the hazardous chemicals used in the stimulation fluid, the percent by volume of those hazardous chemicals, the total volume or water used and a list of the water sources used under an approved water management plan. Final-form § 78.122(c) provides that a well operator may designate any trade secrets or confidential proprietary information in the completion report and the Department will prevent disclosure of confidential information to the extent permitted by the Right-to-Know Law. Additionally, § 78.122(d) specifies that the operator shall maintain records of every chemical used to hydraulically fracture the well and provide those records to the Department upon request.
Both the residents of this Commonwealth and the regulated community will benefit from this final-form rulemaking.
The public will benefit in several ways. The updated casing and cementing requirements will provide an increased degree of protection for homeowners and both public and private water supplies. The construction standards will align the Commonwealth's regulations with other states' rules as well as current industry standards. Pressure testing the casing and testing surface casing seats will detect construction deficiencies before a well could create a potential safety or environmental problem. Minimizing annular pressure will reduce the potential for gas migration. The new quarterly inspections and annual reporting will be a vital tool for operators to use in detecting potential safety or environmental impacts before they may become an issue. The final-form rulemaking also outlines the procedures the operator and the Department will utilize if there is a reported gas migration incident.
The new construction standards and the well remediation measures will far outweigh the liability to the operator from the potential impacts to public safety and harm to the environment from gas migration or from polluting water resources that may result without these additional precautions. As new areas of this Commonwealth are developed for natural gas, this final-form rulemaking will avoid many potential health, safety and environmental issues.
This final-form rulemaking will impose minimal additional cost on the Department. This final-form rulemaking will help the Department offset potential health, safety and environmental issues.
The Department finds that most gas migration issues stem from inadequate cementing procedures, cement returns or combinations of inadequate casing and cementing or over-pressured casing seats. Because many of the Marcellus Shale well operators meet or exceed the current well casing and cementing regulations, any increased cost associated with drilling and operating oil and gas wells will be minimal. All of the potential increases in cost to an operator will be associated with assuring a well is properly completed, operated and plugged.
The potential increase in cost is minor when compared to the overall cost of well construction. When cement is not returned to the surface or when excessive pressure is placed on the surface casing seat, the regulations require the operator to install an additional string of casing. The construction cost for the additional string of casing is about $10,000 per well.
Some commentators questioned the Department's estimate for the additional string of casing, stating that the cost of an additional casing string is much more than $10,000 per well and is more likely on the order of $300,000 to $500,000 per well, depending on depth and area. The commentators stated that if the additional string of casing is justified from a technical standpoint, then it is the correct course of action. The final-form rulemaking does not provide a technical justification for an additional casing string.
The added expense described by the commentators does not apply to situations when cement is not returned to the surface. When production casing is run and set on a packer or casing is set 50 feet deeper than the surface casing, the Department's estimate is sound. Instead, the scenario described more directly relates to the Board's decision to prohibit operators from comingling fresh groundwater with brine by setting very deep surface casing. By setting deep surface casing, operators avoid using deeper intermediate casing and costly cement and cementing practices.
The proposed casing design advocated by the commentators has resulted in several recent gas migration cases in this Commonwealth. These gas migration cases threaten the lives and safety of the citizens of this Commonwealth. The Board did not consider the expense of an intermediate string of casing when it crafted the regulations because the casing design advocated by the commentator results in an unlawful condition. Prohibiting gas migration is the cornerstone of these regulations and compromising on the issue to save money on a necessary string of casing is not acceptable.
Used casing, welded casing and casing attached to a blow-out preventer must be pressure tested to demonstrate its ability to withstand the highest anticipated working pressures to which the casing will be exposed. If the casing fails this test, the operator shall repair or replace the casing and ultimately pass the pressure test. The cost to repair or replace the defective casing is completely outweighed by the environmental damage that would result from a failed string of casing and the fact that the casing would still need to be repaired or replaced.
The typical cost to develop a Marcellus Shale well is around $5,000,000. The additional cost of compliance would only be approximately 0.2% of the overall cost to develop a Marcellus Shale well.
The typical cost to develop a shallow gas well is $250,000 and the typical cost to develop an oil well is $200,000. In either situation, the additional cost of compliance would only be approximately 4% to 5% of the overall cost of the well.
All of the additional measures reduce the potential for gas migration. If an operator fails to prevent a pollution event of a water supply, the anticipated cost to permanently replace one private water supply would be approximately $4,000 to drill a new water well or $30,000 to provide and permanently pay for a treatment system.
The Department worked extensively with representatives from the regulated community and leaders the several trade organizations. The requirements of this final-form rulemaking are, therefore, well known.
The Department, however, scheduled several training sessions for the regulated community to address the Department's regulatory requirements. The Department will use these training sessions as an opportunity to further educate the industry about the new requirements. Paperwork Requirements
The annual well inspection report, the semiannual production report mandated by Act 15 for operators of Marcellus Shale wells and the additional information required in the completion report will require submittal of two additional forms and additional information on an existing form. The results of gas migration investigations will also require additional reporting obligations.
The Pollution Prevention Act of 1990 (42 U.S.C.A. §§ 13101—13109) established a National policy that promotes pollution prevention as the preferred means for achieving state environmental protection goals. The Department encourages pollution prevention, which is the reduction or elimination of pollution at its source, through the substitution of environmentally friendly materials, more efficient use of raw materials or the incorporation of energy efficiency strategies. Pollution prevention practices can provide greater environmental protection with greater efficiency because they can result in significant cost savings to facilities that permanently achieve or move beyond compliance. This final-form rulemaking incorporates the following pollution prevention provisions and incentives:
This final-form rulemaking will minimize gas migration and provide an increased degree of protection for both public and private water supplies by updating material specifications and performance testing as well as adding more specific design, construction, operational an monitoring requirements. The plugging, water supply replacement and gas migrations reporting regulations have been amended to ensure that public safety and groundwater are protected.
These regulations will be reviewed in accordance with the sunset review schedule published by the Department to determine whether the regulations effectively fulfills the goals for which they were intended.
Under section 5(a) of the Regulatory Review Act (71 P. S. § 745.5(a)), on June 25, 2010, the Department submitted a copy of the notice of proposed rulemaking, published at 40 Pa.B. 3845, to the Independent Regulatory Review Commission (IRRC) and the Chairpersons of the House and Senate Environmental Resources and Energy Committees for review and comment.
Under section 5.1(j.2) of the Regulatory Review Act (71 P. S. § 745.5a(j.2)), on November 17, 2010, the final-form rulemaking was deemed approved by the House and Senate Committees. Under section 5.1(e) of the Regulatory Review Act, IRRC met on November 18, 2010, and approved the final-form rulemaking.
(3) These regulations do not enlarge the purpose of the proposed rulemaking published at 40 Pa.B. 3845.
(a) The regulations of the Department, 25 Pa. Code Chapter 78 are amended by amending §§ 78.1, 78.51, 78.52, 78.55, 78.71—78.73, 78.76, 78.81, 78.82, 78.83, 78.84, 78.85, 78.92—78.96, 78.121 and 78.122; and by adding §§ 78.75a, 78.83a, 78.83b, 78.83c, 78.88 and 78.89 to read as set forth in Annex A, with ellipses referring to the existing text of the regulations.
(Editor's Note: The amendment of § 78.55 was not included in the proposed rulemaking at 40 Pa.B. 3845.)
(c) The Chairperson of the Board shall submit this order and Annex A to IRRC and the Senate and House Environmental Resources and Energy Committees as required by the Regulatory Review Act.
(Editor's Note: For the text of the order of the Independent Regulatory Review Commission relating to this document, see 40 Pa.B. 7000 (December 4, 2010).)
Fiscal Note: Fiscal Note 7-459 remains valid for the final adoption of the subject regulations.
(b) The following words and terms, when used in this chapter, have the following meanings, unless the context clearly indicates otherwise: * * * * *
Casing seat—The depth to which casing is set.
Cement—A mixture of materials for bonding or sealing that attains a 7-day maximum permeability of 0.01 millidarcies and a 24-hour compressive strength of at least 500 psi in accordance with applicable standards and specifications.
Cement job log—A written record that documents the actual procedures and specifications of the cementing operation.
Intermediate casing—A string of casing set after the surface casing and before production casing, not to include coal protection casing, that is used in the wellbore to isolate, stabilize or provide well control.
Reportable release of brine—Spilling, leaking, emitting, discharging, escaping or disposing of one of the following:
(i) More than 5 gallons of brine within a 24-hour period on or into the ground at the well site where the total dissolved solids concentration of the brine is equal or greater than 10,000 mg/l.
(ii) More than 15 gallons of brine within a 24-hour period on or into the ground at the well site where the total dissolved solids concentration of the brine is less than 10,000 mg/l.
Seasonal high groundwater table—The saturated condition in the soil profile during certain periods of the year. The condition can be caused by a slowly permeable layer within the soil profile and is commonly indicated by the presence of soil mottling.
Surface casing—A string or strings of casing used to isolate the wellbore from fresh groundwater and to prevent the escape or migration of gas, oil or other fluids from the wellbore into fresh groundwater. The surface casing is also commonly referred to as the water string or water casing.
Unconventional formations—Formations that typically produce gas through the use of enhanced drilling or completion technologies such as the Rhinestreet, Burket, Marcellus, Mandata and Utica Shale formations, or other formations identified by the Department.
Subchapter C. ENVIRONMENTAL PROTECTION PERFORMANCE STANDARDS
§ 78.51. Protection of water supplies.
(a) A well operator who affects a public or private water supply by pollution or diminution shall restore or replace the affected supply with an alternate source of water adequate in quantity and quality for the purposes served by the supply as determined by the Department.
(b) A landowner, water purveyor or affected person suffering pollution or diminution of a water supply as a result of drilling, altering or operating an oil or gas well may so notify the Department and request that an investigation be conducted. The notice and request must include the following:
(1) The name, address and telephone number of the person requesting the investigation.
(2) The type, location and use of the water supply.
(3) Available background quality and quantity data regarding the water supply, if known.
(4) Well depth, pump setting and water level, if known.
(5) A description of the pollution or diminution.
(c) Within 10 days of the receipt of the investigation request, the Department will investigate the claim and will, within 45 days of receipt of the request, make a determination. If the Department finds that pollution or diminution was caused by the drilling, alteration or operation activities or if it presumes the well operator responsible for polluting the water supply of the landowner or water purveyor under section 208(c) of the act (58 P. S. § 601.208(c)), the Department will issue orders to the well operator necessary to assure compliance with this section.
(d) A restored or replaced water supply includes any well, spring, public water system or other water supply approved by the Department, which meets the criteria for adequacy as follows:
(1) Reliability, cost, maintenance and control. A restored or replaced water supply, at a minimum, must:
(iv) Provide the water user with as much control and accessibility as exercised over the previous water supply.
(v) Not result in increased costs to operate and maintain. If the operating and maintenance costs of the restored or replaced water supply are increased, the operator shall provide for permanent payment of the increased operating and maintenance costs of the restored or replaced water supply.
(2) Quality. The quality of a restored or replaced water supply will be deemed adequate if it meets the standards established under the Pennsylvania Safe Drinking Water Act (35 P. S. §§ 721.1—721.17), or is comparable to the quality of the water supply before it was affected by the operator if that water supply did not meet these standards.
(3) Adequate quantity. A restored or replaced water supply will be deemed adequate in quantity if it meets one of the following as determined by the Department:
(i) It delivers the amount of water necessary to satisfy the water user's needs and the demands of any reasonably foreseeable uses.
(ii) It is established through a connection to a public water supply system that is capable of delivering the amount of water necessary to satisfy the water user's needs and the demands of any reasonably foreseeable uses.
(iii) For purposes of this paragraph and with respect to agricultural water supplies, the term reasonably foreseeable uses includes the reasonable expansion of use where the water supply available prior to drilling exceeded the actual use.
(4) Water source serviceability. Replacement of a water supply includes providing plumbing, conveyance, pumping or auxiliary equipment and facilities necessary for the water user to utilize the water supply.
(e) If the water supply is for uses other than human consumption, the operator shall demonstrate to the Department's satisfaction that the restored or replaced water supply is adequate for the purposes served by the supply.
(f) Tank trucks or bottled water are acceptable only as temporary water replacement for a period approved by the Department and do not relieve the operator of the obligation to provide a restored or replaced water supply.
(g) If the well operator and the water user are unable to reach agreement on the means for restoring or replacing the water supply, the Department or either party may request a conference under section 501 of the act (58 P. S. § 601.501).
(h) A well operator who receives notice from a landowner, water purveyor or affected person that a water supply has been affected by pollution or diminution, shall report receipt of notice from an affected person to the Department within 24 hours of receiving the notice.
§ 78.52. Predrilling or prealteration survey.
(a) A well operator who wishes to preserve its defense under section 208(d)(1) of the act (58 P. S. § 601.208 (d)(1)) that the pollution of a water supply existed prior to the drilling or alteration of the well shall conduct a predrilling or prealteration survey in accordance with this section.
(b) A person who wishes to document the quality of a water supply to support a future claim that the drilling or alteration of the well affected the water supply by pollution may conduct a predrilling or prealteration survey in accordance with this section.
(c) The survey shall be conducted by an independent certified laboratory. A person independent of the well owner or well operator, other than an employee of the certified laboratory, may collect the sample and document the condition of the water supply, if the certified laboratory affirms that the sampling and documentation is performed in accordance with the laboratory's approved sample collection, preservation and handling procedure and chain of custody.
(d) An operator electing to preserve its defenses under section 208(d)(1) of the act shall provide a copy of the results of the survey to the Department and the landowner or water purveyor within 10-business days of receipt of the results. Test results not received by the Department within 10 business days may not be used to preserve the operator's defenses under section 208(d)(1) of the act.
(e) The report describing the results of the survey must contain the following information:
(1) The location of the water supply and the name of the surface landowner or water purveyor.
(2) The date of the survey, and the name of the certified laboratory and the person who conducted the survey.
(3) A description of where and how the sample was collected.
(4) A description of the type and age, if known, of the water supply, and treatment, if any.
(5) The name of the well operator, name and number of well to be drilled and permit number if known.
(6) The results of the laboratory analysis.
(f) A well operator who wishes to preserve the defense under section 208(d)(2) of the act that the landowner or water purveyor refused the operator access to conduct a survey shall confirm the desire to conduct this survey and that access was refused by issuing notice to the person by certified mail, or otherwise document that access was refused. The notice must include the following:
(1) The operator's intention to drill or alter a well.
(2) The desire to conduct a predrilling or prealteration survey.
(3) The name of the person who requested and was refused access to conduct the survey and the date of the request and refusal.
(4) The name and address of the well operator and the address of the Department, to which the water purveyor or landowner may respond.
§ 78.55. Control and disposal plan.
(a) Prior to generation of waste, the well operator shall prepare and implement a plan under § 91.34 (relating to activities utilizing pollutants) for the control and disposal of fluids, residual waste and drill cuttings, including tophole water, brines, drilling fluids, additives, drilling muds, stimulation fluids, well servicing fluids, oil, production fluids and drill cuttings from the drilling, alteration, production, plugging or other activity associated with oil and gas wells.
(b) The plan must identify the control and disposal methods and practices utilized by the well operator and be consistent with the act, The Clean Streams Law (35 P. S. §§ 691.1—691.1001), the Solid Waste Management Act (35 P. S. §§ 6018.101—6018.1003) and §§ 78.54, 78.56—78.58 and 78.60—78.63. The plan must also include a pressure barrier policy that identifies barriers to be used during identified operations.
(c) The operator shall revise the plan prior to implementing a change to the practices identified in the plan.
(d) A copy of the plan shall be provided to the Department upon request and shall be available at the well site during drilling and completion activities for review.
(e) A list of emergency contact phone numbers for the area in which the well site is located must be included in the plan and be prominently displayed at the well site during drilling, completion or alteration activities. [Continued on next Web Page]