c.Problems or irregularities during the tests are to be recorded along with actions taken to remedy same in the driller's report.
d.All reports pertaining to diverter function and/or pressure tests are to be retained for inspection at the wellsite for the duration of drilling operations.
C.BOP Systems. The operator shall design, install, use, maintain and test the BOP system to ensure well control during drilling, workover and all other appropriate operations. The surface BOP stack shall be installed before drilling below surface casing. The BOP stack shall consist of an annular preventer and the appropriate number of ram-type preventers necessary to control the well under all potential conditions that might occur during the operations being conducted. The pipe rams shall be of proper size(s) to fit the drill pipe in use.
D.BOP Working Pressure. The working pressure rating of any BOP component shall exceed the maximum anticipated surface pressure (MASP) to which it may be subjected.
E.BOP Auxiliary Equipment. All BOP systems shall be equipped and provided with the following.
1.A hydraulically actuated accumulator system which shall provide 1.5 times volume of fluid capacity to close and hold closed all BOP components, with a minimum pressure of 200 psig above the pre-charge pressure without assistance from a charging system.
2.A backup to the primary accumulator-charging system, supplied by a power source independent from the power source to the primary, which shall be sufficient to close all BOP components and hold them closed.
3.Accumulator regulators supplied by rig air without a secondary source of pneumatic supply shall be equipped with manual overrides or other devices to ensure capability of hydraulic operation if the rig air is lost.
4.At least one operable remote BOP control station in addition to the one on the drilling floor. This control station shall be in a readily accessible location away from the drilling floor. If a BOP control station does not perform properly, operations shall be suspended until that station is operable.
5.A drilling spool with side outlets, if side outlets are not provided in the body of the BOP stack, to provide for separate kill and choke lines.
6.Choke and kill lines each equipped with two full-opening valves. At least one of the valves on the choke line and the kill line shall be remotely controlled. In lieu of remotely controlled valves, two readily-accessible manual valves may be installed provided that a check valve is placed between the manual valves and the pump.
7.A valve installed below the swivel (upper kelly cock), essentially full-opening, and a similar valve installed at the bottom of the kelly (lower kelly cock). A wrench to fit each valve shall be stored in a location readily accessible to the drilling crew.
8.An essentially full-opening drill-string safety valve in the open position on the rig floor shall be available at all times while drilling operations are being conducted. This valve shall be maintained on the rig floor to fit all connections that are in the drill string. A wrench to fit the drill-string safety valve shall be stored in a location readily accessible to the drilling crew.
9.A safety valve shall be available on the rig floor assembled with the proper connection to fit the casing string being run in the hole.
10.Locking devices installed on the ram-type preventers.
F.BOP Maintenance and Testing Requirements
1.The BOP system shall be visually inspected on a daily basis.
2.Pressure tests (low and high pressure) of the BOP system are to be conducted at the following times and intervals:
a.during a shop test prior to transport of the BOPs to the drilling location;
b.immediately following installation of the BOPs;
c.within 14 days of the previous BOP pressure test;
d.before drilling out each string of casing or liner (The District Manager may require that a Conservation Enforcement Specialist witness the test prior to drilling out each casing string or liner);
e.before a well is drilled to a depth that is within 1000 feet of a hydrogen sulfide zone (The District Manager may require that a Conservation Enforcement Specialist witness the test prior to drilling to a depth that is within 1000 feet of a hydrogen sulfide zone);
f.when the BOP tests are postponed due to well control problem(s), the BOP test is to be performed on the first trip out of the hole, and reasons for postponing the testing are to be recorded in the driller’s report.
3.Low pressure tests (200-300 psig) of the BOP system (choke manifold, kelly valves, drill-string safety valves, etc.) are to be performed at the times and intervals specified in LAC 43:XIX.111.F.2. in accordance with the following provisions:
a.test pressures are to be held for a minimum of 5 minutes;
b.variable bore pipe rams are to be tested against the largest and smallest sizes of pipe in use, excluding drill collars and bottom hole assembly;
c.bonnet seals are to be tested before running the casing when casing rams are installed in the BOP stack.
4.High pressure tests of the BOP system are to be performed at the times and intervals specified in LAC 43:XIX.111.F.2 in accordance with the following provisions:
a.test pressures are to be held for a minimum of 5 minutes;
b.ram-type BOP's, choke manifolds, and associated equipment are to be tested to the rated working pressure of the equipment or 500 psi greater than the calculated MASP for the applicable section of the hole;
c.annular-type BOPs are to be tested to 70 percent of the rated working pressure of the equipment.
5.The annular and ram-type BOPs with the exception of the blind-shear rams are to be function tested every 7 days between pressure tests. All BOP test records should be certified (signed and dated) by the operator’s representative.
a.Blind-shear rams are to be tested at all casing points and at an interval not to exceed 30 days.
G.BOP Record Keeping. The time, date and results of pressure tests, function tests, and inspections of the BOP system are to be recorded in the driller’s report and are to be retained for inspection at the wellsite for the duration of drilling operations.
Louisiana Register Vol. 34, No. 10 October 20, 2008