(a) The operator shall use blow-out
prevention equipment after setting casing with a competent casing seat in the
following circumstances:
(1) When drilling
out solid core hydraulic fracturing plugs to complete a well.
(2) When well head pressures or natural open
flows are anticipated at the well site that may result in a loss of well
control.
(3) When the operator is
drilling in an area where there is no prior knowledge of the pressures or
natural open flows to be encountered.
(4) On wells regulated by the Oil and Gas
Conservation Law (58 P.S. §§
401-419).
(5) When drilling within 200 feet of a
building.
(b) Blow-out
prevention equipment used must be in good working condition at all
times.
(c) Controls for the blow-out
preventer shall be accessible to allow actuation of the equipment. Additional
controls for a blow-out preventer with a pressure rating of greater than 3,000
psi, not associated with the rig hydraulic system, shall be located at least 50
feet away from the drilling rig so that the blow-out preventer can be actuated
if control of the well is lost.
(d)
The operator shall use pipe fittings, valves and unions placed on or connected
to the blow-out prevention systems that have a working pressure capability that
exceeds the anticipated pressures.
(e) The operator shall conduct a complete
test of the ram type blow-out preventer and related equipment for both pressure
and ram operation before placing it in service on the well. The operator shall
test the annular type blow-out preventer in accordance with the manufacturer's
published instructions, or the instructions of a professional engineer, prior
to the device being placed in service. Blow-out prevention equipment that fails
the test may not be used until it is repaired and passes the test.
(f) When the equipment is in service, the
operator shall visually inspect blow-out prevention equipment during each tour
of drilling operation and during actual drilling operations test the pipe rams
for closure daily and the blind rams for closure on each round trip. When more
than one round trip is made in a day, one daily closure test for blind rams is
sufficient. Testing shall be conducted in accordance with American Petroleum
Institute publication API RP53, "API Recommended Practice for Blowout
Prevention Equipment Systems for Drilling Wells," or other procedure approved
by the Department. The operator shall record the results of the inspection and
closure test in the drillers log before the end of the tour. If blow-out
prevention equipment is not in good working order, drilling shall cease when
cessation of drilling can be accomplished safely and not resume until the
blow-out prevention equipment is repaired or replaced and retested.
(g) All lines, valves and fittings between
the closing unit and the blow-out preventer stack must be flame resistant and
have a rated working pressure that meets or exceeds the requirements of the
blow-out preventer system.
(h) When
a blowout preventer is installed or required under subsection (a), there shall
be present on the well site an individual with a current certification from a
well control course accredited by the International Association of Drilling
Contractors or other organization approved by the Department. The certification
shall be available for review at the well site. The Department will maintain a
list of approved accrediting organizations on its web site.
(i) Well drilling and completion operations
requiring pressure barriers, as identified by the operator under §
78.55(b)
(relating to control and disposal plan), shall employ at least two mechanical
pressure barriers between the open producing formation and the atmosphere that
are capable of being tested. The mechanical pressure barriers shall be tested
according to manufacturer specifications prior to operation. If during the
course of operations the operator only has one functioning barrier, operations
must cease until additional barriers are added and tested or the redundant
barrier is repaired and tested. Stripper rubber or a stripper head may not be
considered a barrier.
(j) The
minimum amount of intermediate casing that is cemented to the surface to which
blow-out prevention equipment may be attached, shall be in accordance with the
following:
|
Proposed Total Vertical Depth (in
feet)
|
Minimum Cemented Casing Required (in
feet of casing cemented)
|
| Up to 5,000 |
400 |
| 5,001 to 5,500 |
500 |
| 5,501 to 6,000 |
600 |
| 6,001 to 6,500 |
700 |
| 6,501 to 7,000 |
800 |
| 7,001 to 8,000 |
1,000 |
| 8,001 to 9,000 |
1,200 |
| 9,001 to 10,000 |
1,400 |
| Deeper than 10,000 |
1,800 |
(k) Upon completion of the drilling
operations at a well, the operator shall install and utilize equipment, such as
a shut-off valve of sufficient rating to contain anticipated pressure,
lubricator or similar device, as may be necessary to enable the well to be
effectively shut-in while logging and servicing the well and after completion
of the well.
