APPENDICES APPWIX A. sources of co2 Al. Tables of Sources Region I Region I1 Region 1 1 1 Region IV ' U s Angeles 334 A2. National Cryo-chemics, Inc. (NCI ) A3. Areas Reported t o have Significant 60 C02 Deposits APPENDIX B. Costs of C02 B1. Basis of Investment Costs B2. Basis of Operating Costs B3. Methods of Price Detennination B.3.1 Cost of Carbon Dioxide by 3 66
Routine surveys of a subsea pipeline off the NE coast of Scotland in 2000 and 2002 revealed the presence of large numbers of encrusting mounds. These were perceived as a potential risk to the integrity of the pipeline and were subject to investigation. The mounds are constructed by sabellarid worms. Individual worms trap sand from turbulent waters, cementing grains to form robust tubes and collectively forming structures up to 0.75 m in diameter, extending over kilometres of pipeline. Growth rates appear to be relatively rapid and the areas occupied increased significantly within the initial period of observation. The mass and surface area of these structures could affect pipeline integrity in two ways: where the pipe is in span a dead load is applied as a direct consequence of the presence of the mounds. In addition, there is an increased lateral live-load as a result of the increase in surface area presented to currents. By contrast, overgrowth of the pipeline may ultimately offer additional protection. This account describes the nature of this novel addition to shallow water pipelines and assesses its likely impact. Observations in 2004 and 2005 indicated substantial reductions in the areas covered by sabellarid colonies and here at least whatever risk they may present has so far proved transitory.
Initially not part of the project design, one of the most significant design challenges of the BP Bombax Pipeline Project was the design, fabrication, and installation of a 48-inch pipeline subsea manifold. The manifold is multi-purpose and meets the following project needs:Looping the 40-inch and 48-inch systems;Minimizes seabed congestion around Cassia 'B';Allow early production of gas from Kapok;Allows for isolation of any sub-system for either repair, future expansion, or testing;Minimized the installation activities;Facilitates diver access and minimizes the number of subsea tie-in's;Ties-in the Cassia 'B' to Kapok import and the 48-inch export pipelines;Provided a secure location for the Cassia 'B' pipeline ESD isolation valves;Facilitates crossings of the existing pipelines;Provide for future expansion of the gas transportation system and provision for additional field expansion. The manifold was designed:For a 50 year design life;To provide double block-and-bleed isolation of all tie-in's;To withstand the pipeline design loads which included seismic loading;To house the Cassia 'B' platform incoming and export pipeline ESD valves (26-inch fail-closed ESD ball valve and 48-inch check valve) along with the actuated control valve in the 40/48-inch pipeline loop piping;To accommodate the anticipated expansion needs of BP's offshore assets. Procurement of the required 48-inch subsea valves, bends, and fittings provided numerous challenges. As a result the manifold has major components manufactured in 8 different countries. The manifold structure was designed in accordance with API RP 2A and piping in accordance with ASME B31.8 and API RP 1111. Fabrication of the manifold took place in Trinidad and Tobago. Introduction In response to the increasing demand for energy in the form of natural gas, BP Trinidad and Tobago has started expanding its offshore fields and gas transportation system to supply new LNG trains at Point Fortin on the West side of Trinidad as well as the increased local domestic market. There are two projects currently underway to expand production and transportation of gas from 1.5 bscfd to 3.0 bscfd, the Kapok Project and the Bombax Project. The Kapok Project comprises a new 2.6 BCFPD production platform, Cassia 'B' that is bridge connected to the existing Cassia 'A' platform and a new drilling platform Kapok. The Bombax Pipeline Project includes 63 km of 48-inch offshore pipeline from Cassia 'B' to landfall at Rustville, on the East Coast of Trinidad. From the landfall, the pipeline extends 1.8 km onshore to the existing Beachfield slug catcher and production facility for onward transportation of gas to the various industries on the island including the LNG facilities on the West Coast. The offshore end of the 48-inch pipeline is connected to the existing 40-inch pipeline via a 20-inch subsea jumper. This jumper facilitates looping of approximately 2/3's of the existing 40-inch pipeline thereby expand the transportation system capacity.
The paper will present the design of a floating platform incorporating the following systems: Conventional Wind Turbine Long and Short Period Wave Energy Capture Ocean Thermal Energy Conversion (OTEC) Open Flow Current Turbines Energy Storage The focus will be integration of the systems from a structural standpoint; effects on the cost of each system and the resulting LCOE and overnight cost; and the nameplate and peak power for given conditions. Energy mechanisms in the marine environment are the wind, waves, water currents, and seawater temperature differences. An assessment and rating of the energy resource potential of a given development site is used to inform the renewable energy technology system selection process. Offshore Renewable Energy (ORE) technologies can be summarized into the following groups: Offshore Wind Turbines are the prevalent ORE technology exploiting the present market, similar to onshore wind turbines, but mounted upon a fixed or floating offshore platform. Ocean Thermal Energy Conversion (OTEC) uses the temperature differential between surface water and seabed water to drive heat engines. Marine Hydro-Kinetic (MHK) devices convert energy from waves or fluid flow. Wave Energy Converters (WEC) are oscillating/reciprocal/pressure driven systems operating at or near the ocean surface or bottom mounted in shallow waters. Flow Energy Converters (FEC) are used in areas where velocity and direction of water flow is relatively constant or highly predictable if intermittent (tidal). Unlike an onshore wind energy site, offshore wind energy systems (especially floating ones) are surrounded by these other energy sources; the integrated renewable energy facility design process addresses selecting systems that will complement each other while capturing the energy resident in the operating environment, as well as leveraging the wind turbine supporting structure and infrastructure to reduce the costs of the WEC, FEC and OTEC systems. The amount of CAPEX spent on non-power generating equipment can be optimized by leveraging the floating system structure cost to host various ORE technologies. Between 50% and 70% of the overnight cost of a typical MHK or OTEC facility will consist of equipment and activities that do not generate power. This is one of the key differences with offshore wind which has an overnight capital cost overhead of roughly 30%. By combining multiple technologies into a single platform, it is possible to reduce the MHK overhead costs to 18 to 36%, with little or no effect on the offshore wind overhead costs. The resulting design is novel in configuration which takes the form of a Multi-source Articulated Spar Leg (MASL) platform and can reduce the Levelized Cost of Energy (LCOE – the economic measure used to compare energy systems) by at least 25%; can be fabricated and pre-commissioned in port; is fully configurable to the local conditions; is more stable than the current floating wind designs in use; and can be scaled up to carry any sized wind turbine. Both cost savings and an increase in revenue can be realized using integrated ORE facilities given the higher average availability factor offered by blended ORE systems and reduction of individual system OPEX relative to stand-alone ORE systems, and example of which is shown in Illustration of Results A single MASL platform prototype is expected to produce power as cost effectively as the only commercial floating wind farm consisting of 5 spar-type platforms that comprise the Hywind Project. Using published information, the internal rate of return (IRR) of Hywind is between 8% and 10%. The estimated return for the MASL prototype is 8.7%. Both based on a realized electricity price of $0.25/kWh and design life of 25 years.
From October 1973 to June 1976 a caustic steamfloodpilot test projectwas operatad in the Kern River Field of California. The test was conductedin nine adjscent five-spot patternsand utilized Sodium Hydroxideas an additive to the injected steam.The purpose of this paper :[sto present and discuss the operationand rasults of the pilot project. Initial researchand planning processesare descrtbed in addition to comparison of the pilot productionresponsewith other similar patterns in the same area of the field.Tracer and testing programswere initiated in the later stages of the pilot to provide additiGzaldata for analysis of the projecc response. This informationIs presented along with discussionswhich Referencesand illustrationsat end of paper describe the bchavf.or and movement of the Ssdium Hydroxide through the reservotr.From the results of this pilot, recommendat
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