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30 CFR Ch. II (7–1–12 Edition) § 250.616

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30 CFR Ch. II (7–1–12 Edition) § 250.616 § 250.616 30 CFR Ch. II (7–1–12 Edition) (2) You may use a set of hydrau- a well under pressure utilizing equip- lically-operated combination rams for ment specifically designed for that pur- the blind rams and shear rams. pose, i.e., snubbing operations, shall in- (3) You may use a set of hydrau- clude the following: lically-operated combination rams for (1) One set of pipe rams hydraulically the hydraulic two-way slip rams and operated, and the hydraulically-operated pipe rams. (2) Two sets of stripper-type pipe (4) You must attach a dual check rams hydraulically operated with spac- valve assembly to the coiled tubing er spool. connector at the downhole end of the (h) An inside BOP or a spring-loaded, coiled tubing string for all coiled tub- back-pressure safety valve and an es- ing well-workover operations. If you sentially full-opening, work-string plan to conduct operations without downhole check valves, you must de- safety valve in the open position shall scribe alternate procedures and equip- be maintained on the rig floor at all ment in Form BSEE–0124, Application times during well-workover operations for Permit to Modify and have it ap- when the tree is removed or during proved by the District Manager. well-workover operations with the tree (5) You must have a kill line and a installed and using small tubing as the separate choke line. You must equip work string. A wrench to fit the work- each line with two full-opening valves string safety valve shall be readily and at least one of the valves must be available. Proper connections shall be remotely controlled. You may use a readily available for inserting valves in manual valve instead of the remotely the work string. The full-opening safe- controlled valve on the kill line if you ty valve is not required for coiled tub- install a check valve between the two ing or snubbing operations. full-opening manual valves and the pump or manifold. The valves must § 250.616 Blowout preventer system have a working pressure rating equal testing, records, and drills. to or greater than the working pres- (a) BOP pressure tests. When you pres- sure rating of the connection to which sure test the BOP system you must they are attached, and you must in- conduct a low-pressure test and a high- stall them between the well control pressure test for each component. You stack and the choke or kill line. For must conduct the low-pressure test be- operations with expected surface pres- fore the high-pressure test. For pur- sures greater than 3,500 psi, the kill poses of this section, BOP system com- line must be connected to a pump or ponents include ram-type BOP’s, re- manifold. You must not use the kill lated control equipment, choke and line inlet on the BOP stack for taking kill lines, and valves, manifolds, strip- fluid returns from the wellbore. pers, and safety valves. Surface BOP (6) You must have a hydraulic-actu- systems must be pressure tested with ating system that provides sufficient water. accumulator capacity to close-open- close each component in the BOP (1) Low pressure tests. All BOP system stack. This cycle must be completed components must be successfully test- with at least 200 psi above the pre- ed to a low pressure between 200 and 300 charge pressure, without assistance psi. Any initial pressure equal to or from a charging system. greater than 300 psi must be bled back (7) All connections used in the sur- to a pressure between 200 and 300 psi face BOP system from the tree to the before starting the test. If the initial uppermost required ram must be pressure exceeds 500 psi, you must flanged, including the connections be- bleed back to zero before starting the tween the well control stack and the test. first full-opening valve on the choke (2) High pressure tests. All BOP system line and the kill line. components must be successfully test- (g) The minimum BOP-system com- ed to the rated working pressure of the ponents for well-workover operations BOP equipment, or as otherwise ap- with the tree in place and performed by proved by the District Manager. The moving tubing or drill pipe in or out of annular-type BOP must be successfully 130 VerDate Mar<15>2010 13:23 Aug 17, 2012 Jkt 226121 PO 00000 Frm 00140 Fmt 8010 Sfmt 8010 Y:\SGML\226121.XXX 226121 erowe on DSK2VPTVN1PROD with Safety & Environmental Enforcement, Interior § 250.616 tested at 70 percent of its rated work- or the collapse pressure of the coiled ing pressure or as otherwise approved tubing, whichever is less. by the District Manager. (f) Recordings. You must record test (3) Other testing requirements. Variable pressures during BOP and coiled tubing bore pipe rams must be pressure tested tests on a pressure chart, or with a dig- against the largest and smallest sizes ital recorder, unless otherwise ap- of tubulars in use (jointed pipe, seam- proved by the District Manager. The less pipe) in the well. test interval for each BOP system com- (b) Times. The BOP systems shall be ponent must be 5 minutes, except for tested at the following times: coiled tubing operations, which must (1) When installed; include a 10 minute high-pressure test (2) At least every 7 days, alternating for the coiled tubing string. Your rep- between control stations and at stag- resentative at the facility must certify gered intervals to allow each crew to that the charts are correct. operate the equipment. If either con- (g) Operations log. The time, date, and trol system is not functional, further results of all pressure tests, actuations, operations shall be suspended until the inspections, and crew drills of the BOP nonfunctional, system is operable. The system, system components, and ma- test every 7 days is not required for rine risers shall be recorded in the op- blind or blind-shear rams. The blind or erations log. The BOP tests shall be blind-shear rams shall be tested at documented in accordance with the fol- least once every 30 days during oper- lowing: ation. A longer period between blowout (1) The documentation shall indicate preventer tests is allowed when there is the sequential order of BOP and auxil- a stuck pipe or pressure-control oper- iary equipment testing and the pres- ation and remedial efforts are being sure and duration of each test. As an performed. The tests shall be con- alternate, the documentation in the ducted as soon as possible and before operations log may reference a BOP normal operations resume. The reason test plan that contains the required in- for postponing testing shall be entered formation and is retained on file at the into the operations log. facility. (3) Following repairs that require dis- (2) The control station used during connecting a pressure seal in the as- sembly, the affected seal will be pres- the test shall be identified in the oper- sure tested. ations log. For a subsea system, the pod used during the test shall be iden- (c) Drills. All personnel engaged in well-workover operations shall partici- tified in the operations log. pate in a weekly BOP drill to famil- (3) Any problems or irregularities ob- iarize crew members with appropriate served during BOP and auxiliary equip- safety measures. ment testing and any actions taken to (d) Stump tests. You may conduct a remedy such problems or irregularities stump test for the BOP system on loca- shall be noted in the operations log. tion. A plan describing the stump test (4) Documentation required to be en- procedures must be included in your tered in the operation log may instead Form BSEE–0124, Application for Per- be referenced in the operations log. All mit to Modify, and must be approved records including pressure charts, oper- by the District Manager. ations log, and referenced documents (e) Coiled tubing tests. You must test pertaining to BOP tests, actuations, the coiled tubing connector to a low and inspections, shall be available for pressure of 200 to 300 psi, followed by a BSEE review at the facility for the du- high pressure test to the rated working ration of well-workover activity. Fol- pressure of the connector or the ex- lowing completion of the well- pected surface pressure, whichever is workover activity, all such records less. You must successfully pressure shall be retained for a period of 2 years test the dual check valves to the rated at the facility, at the lessee’s filed of- working pressure of the connector, the fice nearest the OCS facility, or at an- rated working pressure of the dual other location conveniently available check valve, expected surface pressure, to the District Manager. 131 VerDate Mar<15>2010 13:23 Aug 17, 2012 Jkt 226121 PO 00000 Frm 00141 Fmt 8010 Sfmt 8010 Y:\SGML\226121.XXX 226121 erowe on DSK2VPTVN1PROD with § 250.617 30 CFR Ch. II (7–1–12 Edition) (h) Subsea BOPs. Stump test a subsea (2) You must visually inspect your BOP system before installation. You BOP system and marine riser at least must: once each day if weather and sea condi- (1) Test all ROV intervention func- tions permit. You may use television tions on your subsea BOP stack during cameras to inspect this equipment. The the stump test. You must also test at District Manager may approve alter- least one set of rams during the initial nate methods and frequencies to in- test on the seafloor.
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