Unless the context otherwise requires, the words hereinafter
defined shall have the following meaning when found in this rule, to
wit:
(d)
"Fluid" means material or substance which flows or moves whether in a
semisolid, liquid sludge, gas, or any other form or state.
1.
Prohibition of Unauthorized
Injection
A. Any underground
injection, except as authorized by permit or rule issued under this Class II
Program is prohibited. The construction or conversion of any well required to
have a permit is prohibited until the permit is issued. Injection fluids
authorized for injection under this Class II Program include those:
1 which are brought to the surface in
connection with conventional oil and natural gas drilling and production and
may be commingled with waste waters from gas processing plants which are an
integral part of production operations, unless those fluids are classified as
hazardous waste at the time of injection;
2 for enhanced recovery of oil and natural
gas; and
3 for storage of
hydrocarbons which are liquid at standard temperature and pressure.
B. Underground injection permits
shall be issued only when the operator shows that there will be no endangerment
of an underground source of drinking water.
1
Underground injection endangers drinking water sources if such injection may
result in the presence of any contaminant in underground water, which supplies
or can reasonably be expected to supply any public water system, and if the
presence of such contaminant may result in such system's not complying with any
National Primary Drinking Water Regulation or may otherwise adversely affect
the health of persons.
2
"Underground Source of Drinking Water (USDW)" shall mean an aquifer or its
portion:
a which currently supplies any public
water system(s); or
b which
contains a sufficient quantity of ground water to supply a public water system;
and
i currently supplies drinking water for
human consumption; or
ii contain s
fewer than 10,000 mg/l total dissolved solids (10,000 ppm); and
c which is not an exempted
aquifer.
C.
Existing enhanced recovery injection, produced fluid disposal or liquid
hydrocarbon storage wells operating under permits issued by the State Oil and
Gas Board (Board) are authorized by rule and not required to reapply for a new
permit. However, these wells are subject to the mechanical integrity,
confinement of fluids, operating, monitoring and reporting, pressure
limitation, casing, cementing, plugging and abandonment, and financial
responsibility requirements of this rule (63) or Rule 64 as applicable. The
State Oil and Gas Board can require that individual wells be permitted on a
case by case basis.
D. The
provisions and requirements of this rule shall apply to underground injection
by Federal Agencies, State Agencies, or any other party, whether or not
occurring on property owned or leased by the United States.
E. Financial Responsibility
1 New Permits
Upon the effective date of this rule, no new permit for an
enhanced recovery injection well, produced fluid disposal well or liquid
hydrocarbon storage well shall be issued to an operator until the requirements
of this Sub-Part E (Financial Responsibility) are met.
2 Existing Permits
All existing holders of permits issued by the Board for
operation of enhanced recovery injection wells, produced fluid disposal wells
or liquid hydrocarbon storage wells shall be required to show cause why the
permit should not be revoked by the Board after notice and hearing, unless the
holder of the permit meets the requirements of this Sub-Part E (Financial
Responsibility) by May 31, 1989.
3 Proof of Financial Responsibility
All applicants for enhanced recovery injection wells,
produced fluid disposal wells or liquid hydrocarbon storage wells must submit
evidence to assure that the resources necessary to close, plug and abandon the
injection wells are available. This surety must be in a form approved by the
Supervisor, and must provide assurance of financial responsibility in the
amount of the total estimated plugging costs. If the surety is in the form of a
Letter of Credit or Surety Bond, it shall be issued by a financial institution
approved by the Supervisor. Evidence of financial responsibility accepted by
the Board must be maintained by the operator on an annual basis.
2.
Notice and Hearing
A. The applicant shall give notice to all
parties in interest and the surface owner, without having to name such parties
or surface owner, (applicant shall identify and submit on a list with the
Permit application, the names and addresses of all owners of record of land
within the AOR), by publishing notice of the application in a newspaper of
general circulation in this state and also in a newspaper of general
circulation in the county where the well will be located and in the manner and
form approved by the Board. If the application is for the initial application
for fluid injection into a producing reservoir (pool), such notice by
publication shall also be given to all operators of wells in the producing
reservoir (pool) without having to name such operators. The applicant shall
file proof of publication prior to the hearing or administrative approval. See
Rules of Order and Procedure for Hearings Before Board.
B. A hearing shall be held on all
applications provided, however, that where said application is not contested
when called for hearing, then sworn affidavits, exhibits and Board forms may be
received in evidence at the hearing as to the manner in which the injection
well, or wells, which are the subject of the application, are to be completed
and regardless of whether or not the Board has previously approved, after
notice and hearing of witnesses, a similar application for the pool or field.
Applications requesting exceptions to this rule (63) shall
require testimony before the Board to justify such exceptions. Any exception(s)
granted and allowed by the Board after notice and hearing shall provide that
the operator must show that such exception(s) shall not endanger any USDW.
3.
Duration of
Permits
A. Permits authorizing
injection into enhanced recovery injection, produced fluid disposal and liquid
hydrocarbon storage wells shall remain valid for the life of the well unless
revoked by the Board for cause, after notice and hearing, or unless mechanical
integrity is lost as prescribed in Part 7 of this rule (63). Loss of mechanical
integrity will automatically suspend permit authorization. If mechanical
integrity is not restored and a concurrent or subsequent mechanical integrity
test passed within ninety (90) days, after written notice from the Supervisor,
the operator shall be required to show cause at a hearing before the Board why
the permit should not be cancelled and the well be plugged and abandoned in
accordance with Part 10 of this rule (63).
B. A permit authorizing underground injection
may be modified, revoked and re-issued after modifications, or cancelled during
its term for cause after notice and hearing. This may be at the request of any
interested person or at the Board's initiative. All requests shall be in
writing and shall contain facts or reasons supporting the request.
C. A permit may be modified, revoked and
re-issued, or terminated after notice and hearing, if:
1 there is a substantial change of conditions
in the enhanced recovery injection, produced fluid disposal or liquid
hydrocarbon storage operations, or there are substantial changes in the
information originally furnished; or
2 information as to the permitted operation
indicates that the cumulative effects on the environment are detrimental, such
as endangerment of USDW's; or
3
there are violations of the terms and provisions of the permit; or
4 the operator has misrepresented any
material facts during the permit issuance process.
4.
Transfer
of Permits
Permits authorizing enhanced recovery injection, produced
fluid disposal or liquid hydrocarbon storage wells may be transferred from one
operator to another, without notice and hearing, upon the filing of the Oil and
Gas Board Form No. 2, Change of Operator, with the appropriate fee, proof of
financial responsibility of new operator as stated in Part 1 (E)(3) of this
rule (63), and approval by the Supervisor. All permit conditions shall apply to
the new operator including financial responsibility as stated in Part 1(E) of
this rule (63), and approval by the Supervisor. All permit conditions shall
apply to the new operator.
5.
Application Requirements
(Individual Well or Project) for New Enhanced Recovery Injection or Produced
Fluid Disposal Wells (Note: liquid hydrocarbon storage well
requirements are detailed in Rule 64). [A new injection well is any well not
presently permitted as a Class II Well, regardless of whether it has ever been
permitted as such.]
A. The application for a
new enhanced recovery injection or produced fluid disposal well shall be made
on Oil and Gas Board Form No. 2 and the proposed plan of work attached, and
which shall contain the following information:
1 name of operator, field name and well name
and number, section, township and range;
2 geologic name, depth interval and
lithologic description of the injection zone;
3 geologic name and lithologic description of
the confining zone or zones and depth interval(s);
4 size, grade and length of all casing
strings and amount, type and grade of cement used to cement each string in
place and hole size;
5 size, grade
and length of tubing and packer setting depth;
6 estimated average and maximum injection
pressure;
7 estimated average and
maximum injection rate;
8 source of
the injected fluid, and an analysis of the injected fluid;
9 depth and geologic name of the deepest
underground source of drinking water in the field and all other underground
sources of drinking water;
10
depth and geologic name of shallowest zone in the field commercially productive
of hydrocarbons;
11 a schematic
drawing depicting surface and down-hole equipment and construction
features;
12 area of review
a calculations shall be made and filed with
the Board showing calculated radius of pressure influence for the well's
expected injection parameters, using the methods proposed in the U. S.
Department of Commerce National Technical Information Service, P. 680-100498
titled Radius of Pressure Influence of Injection Wells. A map shall be
submitted with the individual well or project permit application for which the
permit is sought which shows the applicable area of review within the
calculated radius (for individual wells - calculated radius from the well; for
an area permit for enhanced recovery projects - the project area plus a
circumscribing area the width of which is the calculated radius); or
b a map shall be submitted with the
individual well or project permit application for which the permit is sought
which shows the applicable area of review (for individual wells - one-quarter
(1/4) mile radius; for an area permit for enhanced recovery projects - the
project area plus a circumscribing area the width of which is one-quarter (1/4)
mile).
c a topographic map (or
other map if a topographic map is unavailable) extending one mile beyond the
property boundaries of the source depicting the facility and each of its intake
and discharge structures; each of its hazardous waste treatment, storage, or
disposal facilities; each well where fluids from the facility are injected
underground; and those wells, springs, and other surface water bodies, and
drinking water wells listed in public records or otherwise known to the
applicant within a quarter mile of the facility property boundary." d) the
application for the approval of an enhanced recovery injection or disposal well
shall include the following information:
i
within the area of review, the map must show location, well name and number of
any existing producing wells, injection wells, abandoned wells and dry
holes;
ii identification of each
operator of a producing well within the area of review;
iii only information of public record is
required to be included on the map.
iv corrective action for wells which are
improperly sealed, completed, or abandoned, the applicant shall also submit a
plan consisting of such steps or modifications as are necessary to prevent
movement of fluid into underground sources of drinking water ("corrective
action").
13
for produced fluid disposal wells, a certification from the applicant that the
proposed injection zone is non-productive of oil or gas and is not an
underground source of drinking water; a sample of formation fluid shall be
obtained and an analysis of such fluid sample supplied to the Board upon
completion of the well;
14 whether
the system is open or closed;
15
information submitted with the application showing that injection into the
proposed zone will not initiate fracturing in the confining zone or cause any
movement of fluids into any USDW; the proper demonstration by the applicant
that the pressure in the well at the depth of injection will not exceed
seventy-five per cent (75%) of the calculated fracture pressure of the
formation or upon proper demonstration and submission of evidence, that a
sufficient thickness of overlying strata exists between the injection zone and
the lowermost USDW to prevent fracturing into the USDW. Calculations shall
accompany this submission of evidence that demonstrate that the maximum
injection pressure will not initiate fracturing in the designated confining
zone of a Class II Well.
16 a copy
of an electric log or radioactive log of the well, if available; in the case of
an undrilled well, submit a geologic description of the zone to be used for
injection, the approximate depth of the proposed zone and an electric log or
radioactive log of the nearest well available.
B. A plan for plugging and abandoning the
well in compliance with Part 10 of this rule (63) and the estimated cost of
such plugging and abandoning operation shall be submitted along with the proof
of financial responsibility required in Part 1:E of this rule
(63).
6.
Construction Requirements for New or Converted Enhanced Recovery Injection and
Produced Fluid Disposal Wells
A.
Each new enhanced recovery injection or produced fluid disposal well shall be
completed, equipped, operated and maintained in a manner designed to assure
confinement of fluids to the interval(s) approved.
B. All new enhanced recovery injection or
produced fluid disposal wells shall be sited in such fashion that they inject
into a formation which is separated from any USDW by a confining zone that is
free of known open faults or fractures within the area of review that are
potential flow conduits.
C. All
newly drilled enhanced recovery injection or produced fluid disposal wells
shall be cased with surface or intermediate casing and cemented to a point at
least one hundred feet (100') into the first confining unit immediately below
the lowermost USDW, or through the entire thickness of the confining unit,
whichever is less, unless long-string casing has cement circulated to the
surface, to prevent the movement of fluids into or between underground sources
of drinking water. The surface or intermediate casing shall have cement
circulated to the surface with uncontaminated returns. If cement is not
circulated to the surface, a cement evaluation log acceptable to the Board
shall be run to evaluate cement adequacy. If the cement is not adequate after
setting, additional cement shall be block-squeezed or added to top off the
casing to surface. The circulation of cement or cement evaluation log must be
witnessed and attested to by the operator and the cementing company. The
operator shall file Oil and Gas Board Form 3 (Well Completion Report)
documenting the circulation of uncontaminated cement or adequacy of cement. The
long-string casing shall also have cement behind it through a confining zone
for at least one hundred feet (100') in an interval between the lowermost USDW
and the injection zone. The casing and cement used in the construction of each
newly drilled well shall be designed to comply with all requirements of this
rule for the life expectancy of the well.
D. The requirements of Part 6:C shall not
apply to existing or newly converted wells if:
1 the wells were cased and cemented in
compliance with existing rules of the Oil and Gas Board in existence at the
time the well was originally drilled; and
2 injection will not result in the movement
of fluids into an underground source of drinking water as defined in this rule
(63) Part 1(B)(2).
E.
Each new or converted enhanced recovery injection or produced fluid disposal
well shall be equipped with tubing set on a mechanical packer. The packer shall
be set below the lowermost USDW and at least 100 feet below the top of
competent cement behind the long string casing. In addition, the packer shall
be set no more than 150 feet above the top perforations.
F. The wellhead shall be equipped so that
tubing and annulus pressures can be recorded for monthly monitoring reports
(obtained from monitored pressure data) by having above-ground pressure
observation valves on the tubing and for each annulus of the well; said valves
shall be equipped with operable one-half inch (1/2") female fittings.
G. The operator shall not proceed with any
down-hole work on a new enhanced recovery injection or produced fluid disposal
well until the operator has notified the State Oil and Gas Board and has
received written permission from the Supervisor. No work shall commence until
the Oil and Gas Board Field Inspector has been given adequate notification in
order to be able to witness the work.
H. Logging Requirements
1 For new wells drilled as enhanced recovery
injection or produced fluid disposal wells,
a
if open-hole logs of a nearby well that would reasonably be expected to depict
the same lithology were not run through the lowermost USDW, the new well shall
be logged from the surface to total depth before casing is set; or
b if logs exist from a nearby well that would
reasonably be expected to depict the same lithology, the new well need only be
logged below the surface casing before long string casing is run; and
c appropriate logs as approved by the Board
and other tests shall be conducted during the drilling and construction of new
enhanced recovery injection or produced fluid disposal wells and shall be
submitted to the Supervisor along with a descriptive report interpreting the
results of that portion of those logs and tests which specifically relate to
(1) a USDW and the confining zone adjacent to it, and (2) the injection
formation and adjacent formations prepared by a knowledgeable log
analyst.
2 For existing
wells or dry holes converted to enhanced recovery injection or produced fluid
disposal wells,
a copies of all logs not on
file with the State Oil and Gas Board shall be submitted with the permit
application, where available;
b
copies of Gamma Ray Correlation Logs and Cement Bond Logs shall be submitted,
including Gamma Ray Correlation and Cement Bond Log for intervals squeeze
cemented, where required.
3 For all enhanced recovery injection wells
and produced fluid disposal wells,
a other
logs such as Temperature Logs, Porosity Logs, Fracture Finder Logs or Density
Logs shall be submitted, if available or required by the Board;
b a portion of the Dual Induction Log shall
be annotated to show:
i the base of the
lowermost USDW;
ii the top and
bottom of the injection zone;
iii
the perforated interval;
iv the
upper and lower confining zones;
v
the top of cement behind the injection casing (verified by appropriate log(s)
or calculations); and
vi the
location of the packer.
I. Testing Requirements:
Before operating any new or converted enhanced recovery
injection or produced fluid disposal well, the tubing/casing annulus or the
long string casing shall be tested under the supervision of the Oil and Gas
Board at a pressure of 500 psig or the maximum authorized injection pressure,
whichever is less, provided no testing pressure shall be less than 300 psig.
The well shall have passed the Mechanical Integrity Test if there is a pressure
loss of no greater than three per cent (3%) for a duration one-half (1/2) hour.
Any leaks in excess of three per cent (3%) pressure loss over one-half (1/2)
hour shall be considered a significant leak.
7.
Mechanical
Integrity
A. An injection well
has mechanical integrity if:
1 there is no
significant leak in the casing, tubing or packer as defined in Part 6:I of this
rule (63);
2 there is no
significant fluid movement into an underground source of drinking water through
vertical channels adjacent to the well bore.
B. One of the following methods must be used
to evaluate the absence of significant leaks as defined in Part 6:I under Part
7:A(1) above:
1 pressure test with
liquid;
2 Monitoring of annulus
pressure.
C. Unless
cement was circulated to the surface with uncontaminated returns and documented
by a Form No. 3, Well Completion Report, filed with the Mississippi State Oil
& Gas Board, one of the following methods must be used to demonstrate the
absence of significant fluid movement under Part 7:A.(2) above:
1 cementing records, including cement
squeezes acceptable to the Board, demonstrating the presence of adequate cement
to prevent such migration; and a Cement Bond Log demonstrating the presence of
adequate cement and adequate bonding to prevent such migration; or
2 the results of a Radioactive Tracer Survey
(RTS) witnessed, after adequate notification, by a representative of the Board
will be accepted in conjunction with cementing records which demonstrate the
presence of adequate cement to prevent migration.
D. Each enhanced oil recovery injection or
produced fluid disposal well shall demonstrate mechanical integrity at least
once every five (5) years. The Supervisor shall prescribe a schedule and mail
notification to the operator to allow for orderly and timely compliance with
this requirement.
E. The operator
shall notify the Supervisor at least forty-eight (48) hours prior to any
testing. Testing shall not commence before the end of the forty-eight (48) hour
period unless authorized by the Supervisor.
F. A complete record of all Mechanical
Integrity Tests shall be made out, verified and placed on file with the Oil and
Gas Board within thirty (30) days after testing.
8.
Operating
Requirements
A. Injection shall
not commence in any Class II Well until all permit requirements have been
reviewed and approved by the Supervisor of the State Oil and Gas Board or his
designee.
B. Injection pressure at
the well head shall not exceed the maximum pressure allowed by the permit. All
wells shall not exceed calculated fracture pressure (enhanced recovery wells
can be excepted after notice and hearing).
C. Injection between the outermost string of
casing protecting underground sources of drinking water and the well bore
(borehole) is prohibited.
D. If the
operator or the Supervisor determines that operation may cause fluid to enter
an unauthorized stratum or escape to the land surface, the operator shall shut
in the well immediately. The operator shall notify the Supervisor by telephone
within twenty-four (24) hours of such occurrence. Injection into the well shall
not be resumed until the Supervisor has determined that the well is in
compliance with all material permit conditions. If such compliance is not
achieved within ninety (90) days, after written notice by the Supervisor, the
operator shall be required to show cause at a hearing before the Board why the
permit should not be cancelled and the well be plugged and abandoned in
accordance with Part 10 of this rule (63).
E. After the completion or recompletion of
any well as an enhanced recovery injection or produced fluid disposal well, the
operator shall file Form No. 3 (Well Completion Report) setting forth all
pertinent information. Actual information shall be submitted for those items
that were estimated or approximated in the permit application.
9.
Monitoring and
Reporting Requirements
A. The
operator shall monitor the nature of the injected fluids at time intervals
sufficiently frequent to yield data representative of their characteristics and
observe injected pressure, flow rate, and cumulative volume at least with the
following frequencies:
i weekly for produced
fluid disposal operations;
ii
monthly for enhanced recovery operations; with the results of (i) and (ii)
being reported monthly on Oil and Gas Board Form 14.
B. All reports submitted to the Oil and Gas
Board shall be signed by a duly authorized representative of the operator and
notarized when indicated on the form.
C. The operator of a new enhanced recovery
injection or produced fluid disposal well shall give written notification to
the Supervisor within thirty (30) days after injection or disposal is
commenced.
D. The operator shall
notify the Supervisor of permanent cessation of injection if an injection well
or project is to be removed from service for a period of six (6) months or more
and give reasons or justification for such cessation of injection. Said
permission shall not exceed one (1) year. After one (1) year, the well, or
wells in a project, shall be plugged and abandoned as outlined in Part 10 of
this rule (63). The operator may request a hearing for an extension exceeding
one (1) year. Wells required for standby service, provided they pass a
mechanical integrity test and meet all requirements for wells in active
service, are exempt from the plugging requirements of this paragraph.
E. The operator shall, within thirty (30)
days, notify the Supervisor of the date injection into an enhanced recovery
injection or produced fluid disposal well or project is permanently terminated
and the reason therefor. The permit authorizing the well or project shall
expire at this time. Notification of project termination must be accompanied by
an individual well status report for all project injection wells.
F. Mechanical failures or down-hole problems
which indicate an enhanced recovery injection or produced fluid disposal well
is not directing fluids into the authorized injection zone may be cause to shut
in the well. If this condition may endanger a USDW, the operator shall orally
notify the Supervisor within twenty-four (24) hours.
Written notice of this failure shall be submitted to the
Supervisor within five (5) days of the occurrence, additionally a plan for
testing and/or repairing the well shall be submitted within thirty (30) days of
the occurrence. Any mechanical down-hole well work performed on the well shall
be witnessed by an oil and gas inspector unless such witnessing is waived by
the Supervisor. Mechanical failures will be treated as loss of mechanical
integrity, and provisions of Part 3:A of this rule (63) will apply.
G. The operator shall retain
records of all monitoring information for a period of three (3)
years.
H. The operator shall
monitor the nature of the injected fluids to obtain data representative of
their characteristics at least once within the first year of the authorization
and, thereafter, when changes in the fluid occur.
10.
Plugging and
Abandoning
A. Prior to abandoning
an enhanced recovery injection or produced fluid disposal well, the well shall
be plugged in a manner which will not allow the movement of fluids either into
or between underground sources of drinking water by:
1 isolating the injection zone from the well
bore by the use of cement plugs; and
2 such other cement plugs as are deemed
necessary by the Board to properly plug the well.
B. Placement of the cement plugs shall be
accomplished by one of the following:
1 the
Balance-Plug Method;
2 the Dump
Bailer Method;
3 the Two-Plug
Method; or
4 an alternative method,
approved by the Supervisor, which will reliably provide a comparable level of
protection to underground sources of drinking water.
C. The well to be abandoned shall be in a
state of static equilibrium with the mud weight equalized top to bottom, either
by circulating the mud in the well at least once or by a comparable method
prescribed by the Supervisor, prior to the placement of the cement
plug(s).
11.
Notification of Down-hole Work
When any produced fluid disposal well permit has been issued
by the Board, the operator shall not proceed with any down-hole work on such
well or the reworking of any existing produced fluid disposal well, including,
but not limited to, any cementing, setting of packer, the running or pulling of
tubing or any work involving subsurface equipment, until the operator has
notified the Supervisor of the State Oil and Gas Board and has received from
the Supervisor written permission to proceed with any such work. The Supervisor
may, in his discretion and in lieu of such written permission, have his
representative present to observe and inspect any such work, in which event the
representative shall file a written report thereof. Notification as to the
time, date and place of the work must be given at least forty-eight (48) hours
prior to commencing the work, unless waived by the Supervisor.
12.
Annular
Disposal
The Board may approve annular disposal of produced fluids for
a period of not more than one (1) year, after notice and hearing provided that
the outermost casing is properly cemented through the lowermost USDW. The
applicant shall provide the Board a Radioactive Tracer Survey (accompanied by
an interpretation of the survey by the company which performed the test) to
prove that the injected fluid is entering the permitted zone and there are no
leaks in the casing. The applicant shall furnish the Board an economic study of
the well and the economics of alternative methods of disposal of the produced
fluids. No permit for annular injection will be granted where a viable economic
alternative is found to exist.
13.
Exemption of
Aquifers After notice and opportunity for public hearing, the
Board may identify (by narrative description, illustrations, maps or other
means) and describe in geographic and/or geometric terms (such as vertical and
lateral limits and gradient) which are clear and definite, all aquifers, or
parts thereof, which the Board proposes to designate as exempted aquifers for
purpose of Class II Underground Injection. In order to be designated as an
exempted aquifer, the following criteria must be met:
A. The aquifer does not currently serve as a
source of drinking water; and
B.
The aquifer cannot now, and will not in the future, serve as a source of
drinking water because:
1 It is mineral
producing, hydrocarbon producing or geothermal energy producing or can be
demonstrated by a permit applicant, as part of a permit application for a Class
II operation, to contain minerals or hydrocarbons that, considering their
quantity and location, are expected to be commercially producible; or
2 It is situated at a depth or location which
makes recovery of water for drinking water purposes economically or
technologically impractical; or
3
It is so contaminated that it would be economically or technologically
impractical to render that water fit for human consumption; or
4 It is located over a Class III Well mining
area subject to subsidence or catastrophic collapse; or
C. The total dissolved solids content of the
ground water is more that 3000 and less that 10,000 mg/l and it is not
reasonably expected to supply a public water system;
D. the aquifer exemption is approved with the
concurrence of the Mississippi Department of Natural Resources and the
Mississippi State Board of Health.
14.
Suspension of
Operations
Should the Supervisor of the State Oil and Gas Board
determine that the continued operation of a well, wells or associated treating,
handling or storage facilities would cause waste, pollution or contamination of
air, surface water, a USDW or soils, he will immediately prohibit further
operation of the well, wells or associated facilities and may suspend the
operator's Certificate of Compliance (Form 8) to transport oil, gas or other
products until such time as it is determined by the Supervisor that the
operator is in compliance with all rules and regulations of the Board.
15.
Penalty
Any person, firm or corporation violating any of these rules
and regulations shall be punished as provided by Section
53-1-47 of
the Mississippi Code Annotated, 1972.
16.
Exceptions
The Board, after notice and hearing, may grant an exception
to any construction or operating provision of this rule upon proof of good
cause. The operator must clearly demonstrate that this exception will not
endanger a USDW. No exception shall be granted by the Board which would be a
violation of any Federal Regulation and/or State of Mississippi Statute.
17.
Effective
Date
This order supersedes Order No. 395-87 of the State Oil and
Gas Board, dated September 17, 1987, and these rules and regulations shall take
effect and be in force from and after April 20, 1989, except where otherwise
provided.
18.
Validity
Should any section, subsection or other provision of this
rule be declared by a court of competent jurisdiction to be invalid, that
decision shall not affect the validity of the rule as a whole or any part
thereof, other than the part so declared to be invalid, this Board hereby
declaring that it would have adopted those parts of this rule which are valid
and omitted any parts which may be invalid, if it had known that such part or
parts were invalid at the time of the adoption of this rule.
