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Well Testing Systems NORSOK STANDARD SYSTEM REQUIREMENTS WELL TESTING SYSTEMS D-SR-007 Rev.1, January 1996 Please note that whilst every effort has been made to ensure the accuracy of the NORSOK standards neither OLF nor TBL or any of their members will assume liability for any use thereof. Well testing systems D-SR-007 Rev. 1, January 1996 CONTENTS 1 FOREWORD 2 2 SCOPE 2 3 NORMATIVE REFERENCES 2 4 DEFINITIONS AND ABBREVIATIONS 3 4.1 Definitions 3 4.2 Abbreviations 3 5 FUNCTIONAL REQUIREMENTS 3 5.1 General 3 5.2 Products/services 3 5.3 Equipment/schematic 4 5.4 Performance/output 5 5.5 Regularity 5 5.6 Process/ambient conditions 5 5.7 Operational requirements 5 5.8 Maintenance requirements 7 5.9 Isolation and sectioning 7 5.10 Layout requirements 7 5.11 Interface requirements 7 5.12 Commissioning requirements 7 6 INFORMATIVE REFERENCES 8 ANNEX A SERVICE DATA SHEETS 9 ANNEX B EQUIPMENT DATA SHEET 19 NORSOK standard 1 of 38 Well testing systems D-SR-007 Rev. 1, January 1996 1 FOREWORD NORSOK (The competitive standing of the Norwegian offshore sector) is the industry initiative to add value, reduce cost and lead time and remove unnecessary activities in offshore field developments and operations. The NORSOK standards are developed by the Norwegian petroleum industry as a part of the NORSOK initiative and are jointly issued by OLF (The Norwegian Oil Industry Association) and TBL (The Federation of Norwegian Engineering Industries). NORSOK standards are administered by NTS (Norwegian Technology Standards Institution). The purpose of this industry standard is to replace the individual oil company specifications for use in existing and future petroleum industry developments, subject to the individual company's review and application. The NORSOK standards make extensive references to international standards. Where relevant, the contents of this standard will be used to provide input to the international standardisation process. Subject to implementation into international standards, this NORSOK standard will be withdrawn. 2 SCOPE This standard describes functional, performance and operational requirements for well testing equipment and systems. 3 NORMATIVE REFERENCES API Spec, 5CT Specification for casing and tubing API RP 7G Recommended practice for drill stem design and operating limits API Spec. 6A Specification for valves and wellhead equipment API Spec. 14A Specification for sub surface safety valve equipment API RP 14C Recommended practice for analysis, design, installation and testing of basic surface safety systems on offshore production platforms API RP 14E Recommended practice for design and installation of offshore production platform piping systems API 17B Recommended practise for flexible pipes API RP 44 Recommended practice for sampling petroleum reservoir fluids API RP 520 Recommended practice for sizing, selection and installation of pressure-relieving devices in refineries API RP 521 Recommended practice for pressure-relieving and depressuring systems DnV Certification Note 2.7-1 Offshore freight containers. Design and certification ASME Section VIII Div. 1 and 2 Rules for construction of pressure vessels ANSI/ASME B31.3 Chemical plant and petroleum refinery piping NACE MR-01-75 Sulphide stress cracking resistant metallic materials for oil field equipment NORSOK standard 2 of 38 Well testing systems D-SR-007 Rev. 1, January 1996 4 DEFINITIONS AND ABBREVIATIONS 4.1 Definitions Normative references Shall mean normative in the application of NORSOK standards. Informative references Shall mean informative in the application of NORSOK standards. Shall Shall is an absolute requirement which shall be followed strictly in order to conform with the standard. Should Should is a recommendation. Alternative solutions having the same functionality and quality are acceptable. May May indicates a course of action that is permissible within the limits of the standard (a permission). Can Can requirements are conditional and indicates a possibility open to the user of the standard. 4.2 Abbreviations None. 5 FUNCTIONAL REQUIREMENTS 5.1 General SI units and Imperial units are used in this specification. SI units with imperial units in brackets shall be used in all documentation. 5.2 Products/services The well testing equipment is grouped in 5 categories: 5.2.1 Drill stem test tools The downhole equipment shall be able to control test production of reservoir fluids into the test tubing, alternatively injection of fluids from tubing into formation. It shall also provide means to establish a permanent or closeable communication between tubing and annulus. 5.2.2 Landing string equipment The landing string equipment shall constitute the safety elements in the test string enabling shutting in the well stream and perform a controlled disconnect at sea floor level. It shall also provide means to lubricate working tools into the test string. 5.2.3 Surface equipment The surface equipment shall be able to receive high pressure well fluid, perform 3 phase separation of the fluid and accurately measure the individual flow stream. Produced water and hydrocarbons shall be disposed off without spill to sea. 5.2.4 Reservoir information acquisition Shall perform acquisition of representative and accurate surface and downhole pressure and temperature measurements during flow production testing of the well. Shall also acquire representative bottom hole and/or surface samples for detailed analysis. NORSOK standard 3 of 38 Well testing systems D-SR-007 Rev. 1, January 1996 5.2.5 Test tubing Shall provide a gastight mean to transport hydrocarbons to surface. 5.3 Equipment/schematic 5.3.1 Drill stem test tools • Packer of permanent or retrievable type. • Tester valve. • Circulating valves. • Slip joint. • Hydraulic jar. • Safety joint. • Auxiliary valves. • Integrated Downhole Data Acquisition Tool. • Subs and x-overs. 5.3.2 Surface equipment • Surface test tree. • Flexible flowline (for floaters). • Rigid flowline (for jack up’s). • Flowline manifold/dataheader. • Chemical injection pumps. • Stand-alone safety valve. • Choke manifold. • Heat exchanger. • Three phase separator. • Surge tank. • Transfer pump. • Crude oil burners. • Control cabin/laboratory. • PSD/ESD system. • Interconnecting piping. • Instrumentation. • Auxiliary equipment. 5.3.3 Landing string equipment • Subsea test tree w/fluted hanger and slick joint. • Lubricator valve. • Retainer valve. • BOP safety valve (for jack-up’s). • Subs and x-over. 5.3.4 Reservoir information acquisition • Pressure and temperature recorders. • Bottom hole sampling equipment. • Surface sampling equipment. NORSOK standard 4 of 38 Well testing systems D-SR-007 Rev. 1, January 1996 • Trace element and wellsite chemistry analysis. • Data acquisition system. • Sand detection equipment. 5.3.5 Test tubing Test tubing. 5.4 Performance/output The provided equipment shall be mobilised, installed, commissioned, operated, maintained and demobilised by competent personnel provided by the contractor. 5.5 Regularity N/A 5.6 Process/ambient conditions Standard eqt. HPHT eqt. Maximum reservoir pressure 690 Bar 1035 Bar Maximum annulus downhole pressure 1035 Bar 1379 Bar Maximum downhole temperature 150ºC 210ºC Maximum wellhead temperature 100ºC 130ºC (175ºC for jack-up’s) Maximum operating temperature -20ºC -20ºC H2S Service Yes Yes CO2 Service Yes Yes All equipment shall be designed for offshore environment with corrosive and salt containing atmosphere. 100 % relative humidity and surface temperature of -20 to 30ºC. 5.7 Operational requirements 5.7.1 Surface equipment The pressure relief system from all relief devices shall be routed to relief headers for high or low pressure relief. It is vendors responsibility to ensure that the relief system is suitably sized to discharge the maximum gas and/or liquid design flow rate. Discharge shall by preference be directed to the flareboom. Alternatively can discharge be routed to dedicated safe area minimum 3 meter below lower deck area. Vessels designed for, or potentially operated as atmospheric vessels shall be equipped with devices or designed so that return of air causing an explosive mixture or backfire into the vessel is prevented. The interconnecting piping system shall by preference be permanently installed with an effort to minimise elastomers in the connections. Permanently installed piping shall be covered with grating where appropriate to provide a safe working environment. Any water dumped overboard shall contain less that 40ppm of hydrocarbons. Discharged water shall be sampled and quantity measured. NORSOK standard 5 of 38 Well testing systems D-SR-007 Rev. 1, January 1996 Burning of hydrocarbons shall take place without pollution to sea. An effort shall be made to minimise smoke and pollution to air where this is not impairing the burning efficiently. API 14C shall be used as a guideline to safeguard the surface process equipment. SAFE, SAC and SAT charts shall be presented. The main process equipment area shall be equipped with coaming to prevent oil spill from spreading outside the dedicated area. Heat radiation calculations shall be presented to Company upon request displaying maximum exposure at maximum production rate in a worst case scenario. When the piping installation has a change of pressure rating (spec. break), the lower rated pipe shall be adequately protected against overpressure. Double isolation valves shall be installed where practical. All surface pressure containing piping and vessels shall be mounted in such a manner that blow- down of the equipment is possible form
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