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<br /> <br />(b) at a pressure equivalent to a gradient of 18 kPa per metre or, at a minimum, the expected <br />reservoir pressure; <br />(c) for a duration of ten (10) minutes; <br />(d) using an incompressible fluid to apply the pressure for the test; and <br />(e) recording and retaining on file the following information: <br />(i) type of fluid and its gradient, <br />(ii) test duration, <br />(iii) initial pressure, and <br />(iv) final pressure. <br />3.12.14, Casing Pressure Test <br />The intermediate string of cemented casing above the main hole shall be successfully pressure <br />tested before the cement is drilled out of the shoe joint. If the test results are not successful, the <br />problem shall be identified and remedial work shall be undertaken. <br />3.12.15. Drilling Main Hole, Production Casing and Cementing <br />Cemented production casing shall protect equipment and formations from anticipated pressures <br />and permanently prevent fluid migration between porous and permeable formations. <br />3.12.16. Minimum Logs <br />An operator shall complete a gamma ray and a neutron log through the entire length of the well <br />bore in all exploratory wells. <br />3.12.17. Wellhead Equipment <br />The operator shall ensure that all valves, nipples, casing and tubing spools, casing and tubing <br />bowls, and changeover flanges and spools installed below the BOP on the wellhead after the last <br />intermediate casing (or surface casing if no intermediate casing) has been installed, comply with <br />API Spec 6A: Valves and Wellhead Equipment. <br />3.12.18. Blow Out Prevention (BOP) <br />The Blowout Prevention (BOP) System for well control shall be installed in accordance with Part 4 <br />and pressure-tested in conjunction with the pressure test of the last string of intermediate casing. <br />3.12.19, Cable Tool Well Control Equipment <br />(a) Prior to drilling of a formation with potential for the flow of natural gas or crude oil, a well <br />control device shall be installed that is; <br />(i) capable of closing around the cable and on the open hole, and <br />(ii) which can be controlled from a remote location; <br />(b) The well control device shall be function tested daily during the drilling of prospective <br />formations. <br />(c) All the components of the lubricator system assembly shall be capable of handling at feast <br />120% of the maximum anticipated pressure. <br />(d) The operator shall specify in the drilling program when a full lubricator system shalt be <br />employed. <br />(e) A full lubricator system shall be required when; <br />17 <br /> <br />