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Collaborating Authors
Production logging
Abstract The objective is to present accurately the performance of the combination of a venturi and multi energy gamma ray in a case study in Venezuela. The focus will be on practical information, knowledge sharing to overcome all classical problems due to fluid behavior met by multiphase metering device in extra heavy oil including classical separator. Heavy and Extra-Heavy Oil represents more than 50% of the worldwide oil reserves, and large efforts have been spent to overcome difficulties related to this kind of oil production. Venezuela has pone of the largest reserve of HO and EHO with more than currently 1.5 trillion of oil in place. Different set of technologies and methodologies have been used to overcome the technical production and monitoring challenges in these lifted or pumped wells. Petroleos de Venezuela (PDVSA) at the opposite of Canada companies is currently producing most of the Heavy Oil from cold and therefore non thermal production methods due to historical reasons. Recently, Orocual field in Monagas Northern (Venezuela) was put in production a cluster with extra heavy oil reaching gravity from 8.6 to 11 API and with a viscosity range from 6 Pa.s to more than 20 Pa.s at line conditions. As per fact, this new production cluster did not have any data, and PDVSA could only use conventional storage tanks to try to estimate the liquid flow rate with no possibility to be able to get the gas production because no separator were able to work in these conditions. However, it was essential to PDVSA in this early phase of the development to review the performance of the field and get access to the oil, water and gas flow rates. In these challenging conditions, and after trying other multiphase meters said to work in Extra Heavy Oil, PDVSA found that the only solution was Venturi - multi energy gamma ray combination. This multiphase technology broke the extra heavy oil paradigm related to multiphase technology to measure flow rates accurately and a comparative test were capable to demonstrate when it was possible from a reference point of view that the overall uncertainty of the entire system (Venturi-Tank) was better than 2%. This extended the new multiphase technology operating envelope for PDVSA from Gas to Extra Heavy Oil and provided a unique solution and the capability to monitor and optimize in real-time the production in this field.
- Government > Regional Government > South America Government > Venezuela Government (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- South America > Venezuela > Monagas > Eastern Venezuela Basin > Maturin Basin > Orocual Field > San Juan Formation (0.99)
- South America > Venezuela > Monagas > Eastern Venezuela Basin > Maturin Basin > Orocual Field > Las Piedras Formation (0.99)
- South America > Venezuela > Monagas > Eastern Venezuela Basin > Maturin Basin > Orocual Field > Carapita Formation (0.99)
- (4 more...)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Oil sand, oil shale, bitumen (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Downhole and wellsite flow metering (1.00)
- Data Science & Engineering Analytics > Information Management and Systems (1.00)
Abstract The use of optical fibers in the oil and gas industry is becoming more viable for several permanent monitoring applications, such as distributed temperature sensing (DTS) and optical pressure transducers. However, long-term performance of fibers, especially at elevated temperatures, is still an issue yet to be fully resolved. This problem is critically important in steam-assisted gravity drainage (SAGD) applications, where wells operate in extreme conditions of high temperatures, often exceeding 250oC, as well as in high pressures within a hydrogen-rich environment. Optical fiber performance is seriously affected by many factors, including:Hydrogen ingression Thermal resistance of the materials Mechanical resistance of the fiber Exposure of optical fibers to hydrogen changes the performance of the fibers through what is referred to in the industry as "hydrogen aging" or "hydrogen darkening." Hydrogen darkening is increased absorption or light loss due to various chemical species in the glass fiber resulting from the presence of hydrogen. Value of DTS in SAGD Applications It is known that temperature monitoring in SAGD wells is of significant importance because it provides a good understanding of the temperature distribution along the horizontal section. Conventionally, thermocouples have been used to measure and monitor the temperature along the horizontal section, and are typically installed at heel, middle and toe of the section. Since thermocouples (TC) inherently provide temperature data at these discrete points, temperature information between the TCs is usually interpolated to understand the temperature distribution. As a result of this interpolation, there could be sections of the wellbore that would require more data from different sources for a detailed analysis instead of just being able to visualize the temperature behavior. Hence, there is a need for a tool that can provide temperature data along the entire length of the horizontal section. In addition, the installation must be simple in order to keep it safe and cost-effective. The optical fiberbased DTS technology has been applied in the past successfully and it is known that the optical fiber-based DTS technique provides temperature data along the entire length of the fiber. This temperature data provides information;, e.g., what sections of the lateral are operating at "sub cool," and enabling users to:Quickly identify anomalies Immediately implement corrective action Allow for better steam utilization
- North America > Canada (0.65)
- North America > United States > Texas (0.28)
- Well Completion > Completion Monitoring Systems/Intelligent Wells (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Thermal methods (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (1.00)
The SpliTigatorTM: A Device for the Mitigation of Phase Splitting
Berger, Eric L. (Texaco Exploration and Production Inc.) | Kolthoff, Karl W. (Texaco Exploration and Production Inc.) | Schrodt, James L.G. (Texaco Exploration and Production Inc.) | Long, S. Lynn (Texaco Inc.) | Pauley, J. Craig (Texaco Inc.)
Abstract Phase splitting at piping junctions in two-phase steam distribution systems results in unequal steam delivery to injection wellheads and interferes with the optimization of injection rates. Texaco's researchers have investigated phase splitting and have devised and evaluated various methods for its mitigation. As a result of these efforts, the SpliTigatorTM, a device for the mitigation of phase splitting, was developed and patented. The SpliTigator is designed to deliver a specific steam quality to the branch leg of a Tee junction. The SpliTigator delivers consistent steam quality as branch flow rate, system pressure, and inlet flow conditions change. SpliTigator pressure losses are small, allowing numerous devices to be used in series. The use of the SpliTigator has been extended to flow rate and steam quality measurement and other two-phase systems. This paper presents an explanation for phase splitting, discusses the theory behind the design and operation of a SpliTigator, and presents results from both laboratory testing and field applications. Introduction The phase splitting behavior which commonly occurs at piping junctions within two-phase piping systems results in unequal distribution of the phases between branches of the junction. In steam distribution systems, inequitable phase splitting results in the delivery of a wide range of steam qualities and mass flow rates to injector wellheads. The SpliTigator is an effective and inexpensive device for the mitigation of phase splitting that has been developed through the joint efforts of Texaco personnel at the Bakersfield Division's Kern River Business Unit and at the Exploration Production Technology Division's Steam Flow Research Facility. An isometric diagram of a SpliTigator is shown in Figure 1. The following summarizes the most significant features of the device. The SpliTigator:โControls branch steam quality within a few quality points of design over a wide range branch flow rates, system pressure, and trunk line steam quality. โCreates no additional pressure drop in the main line and requires very little pressure drop in the branch for effective operation. โRequires no moving parts, no periodic adjustments, and little or no maintenance throughout the life of the steam flood. โIs constructed from off-the-shelf piping components as a drop-in replacement for existing branch Tee junctions. P. 37^
- North America > United States > California > San Joaquin Basin > Kern River Field (0.99)
- Asia > Indonesia > Sumatra > South Sumatra > South Sumatra Basin > Rokan Block > Rokan Block > Duri Field (0.99)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (1.00)
- Facilities Design, Construction and Operation (1.00)
Abstract The newly developed Dielectric Steam Quality Sensor (DSQS) utilizes a unique approach to measuring steam quality. The DSQS actually measures the electrical impedance of the wet steam in an annular cross section between the sensor's electrode and housing. Based on the sensor's dimensions, geometrical cell constants relate the measured impedance of the steam to the dielectric constant and resistivity of the two phase medium. The documented electrical properties of water and vapor, established mixing laws, and the measured impedance are correlated with the liquid volume fraction. The more common "Steam Quality" expression is then computed using specific volumes of the phases at saturation conditions. The DSQS was developed specifically for use in oil industry thermal recovery steam distribution systems. Application points include steam generator discharge, injector wellhead, steam headers, and other selected locations in the piping network. Direct use of the DSQS technology is also anticipated in geothermal industry steam collection systems. This paper presents the theory of operation, the mechanical design, associated instrumentation and results of extensive testing. Laboratory testing conducted in Texaco's Steamflow Research Facility, provided guidance on the optimal mechanical design and demonstrated the concept of relating measured impedance to steam quality. Early field testing was accomplished in the Kern River Field to verify performance in oil field operating conditions. These tests showed the effect of saline field water on the DSQS system and provided the data necessary to development the methodology to incorporate various water resistivities into the impedance measurement. A further evaluation the DSQS system with a broader and more extensive test program was conducted where results were compared to concurrent measurements obtained using portable separator test units. The tests, conducted in various San Joaquin Valley oilfields, document the performance of the DSQS over a broad range of stable and unstable operating conditions. Introduction Enhanced Oil Recovery (EOR) operations are increasing the use of steam flooding to improve production rates and overall recovery in heavy oil reservoirs. Although the injection of "dry" or super-heated steam would transfer more heat into the reservoir, operating costs and practical limitations result in the injection of lower quality steam, usually 80% and below. To optimize the effectiveness of the steam flood and to model the steam flood movement, it is important to accurately know the mass rate and quality of the steam being supplied to each injector well. One can calculate steam quality at the exit of a generator based on consumed fuel, feedwater rate, and associated generator factors. However, as the steam flows through long pipelines and becomes divided into multiple lines, the steam quality at any given point becomes unknown and varies throughout the distribution system. This is due primarily to the fact that "wet" steam is made of two phases, steam vapor and hot water. As the two-phase steam divides at tees or manifolds the proportional mass of the liquid to vapor is not maintained in the outlets. This phenomenon is known as phase splitting and has been the subject of many research studies. Field personnel will often connect a trailer mounted apparatus to the steam line feeding an injector to measure the steam quality at the well-head. The apparatus on the trailer separates the two phases using settling tanks and demisters. Single phase vapor and liquid measurements are then used to calculate steam quality. While this method is accurate, it is time consuming to produce the final measurement and requires the service of skilled personnel. In addition, a trailer-mounted device is quite expensive and alone could not provide a "snapshot" of all the wells in the entire field. P. 23^
- North America > United States > California > Kern County (0.35)
- Europe > United Kingdom > Irish Sea > East Irish Sea > Liverpool Bay (0.25)
- North America > United States > California > San Joaquin Basin > Kern River Field (0.99)
- South America > Brazil > Parnaiba Basin > Block PN-T-68 > California Field (0.89)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Thermal methods (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (1.00)
Abstract A 2100-foot, 14-inch steam line was installed under a ship channel to provide steam to wells on an island location. Designed to operate at 600 F and 1600 PSIG, the line transports wet steam (80% quality) for steamflood injection. The insulated line was installed inside of two concentric casings to allow for 8 feet of thermal expansion and to facilitate installation. Although the design had to overcome uncommon problems, the solutions were based upon using common methods and materials. Introduction Tidelands Oil Production Company operates a steamflood project in the Tar Zone of Fault Block II-A in the Wilmington oil field, Los Angeles County, California (Fig. 1). The steamflood reserves are located within the Ports of Los Angeles and Long Beach and extend from the coastal mainland to Terminal Island. Expansion of steamflood operations required extension of the main 14-inch steam transmission line across a ship channel to Terminal Island (Fig. 2). Steam is supplied from Harbor Cogeneration Plant on the mainland, so the source could not be relocated. The channel crossing was accomplished using conventional directional drilling for pipeline installation to install a 30-inch welded steel casing. This provided a near-linear alignment and allowed the steam line to grow 8 feet longitudinally without overstress. The steam line was anchored to the end of the casing, and the casing was anchored naturally by the surrounding soil. A 24-inch welded steel inner casing was slid over the insulated 14-inch steam line to form a single 2100-foot string, and the dual concentric string was pulled through the 30-inch casing. The inner casing provided secondary protection from groundwater and simplified the installation of the steam line under the channel. The soil over the pipeline provided a thermal insulating layer up to 130 feet thick, which caused the casing and surrounding ground temperature to exceed 300 F. The high temperature raised issues regarding casing integrity and coating. The inaccessibility of supports and guides presented problems with assuring support integrity during installation and operation. The final installation avoided the use of components which would fail under localized heating up to 600 F, and relied on a conservative design and the redundancy of an inner casing. The casings are uncoated, but cathodically protected to reduce corrosion. The steam line supports, clamped over ceramic spacers, were designed for steel on steel sliding surfaces. The anchor design is simple, using standard flange bolting and insulating material, but can accommodate much more than the anticipated loads. Expansion at the free end of the steam line is accommodated by piping flexibility with a single loop. Engineering and Design Type of Crossing. The casing for the steam line was installed by conventional directional drilling for pipeline installation, to a maximum depth of 150 feet below sea level. The crossing consisted of sloped straight segments on each side and a long arc (2500-foot radius) near the center. There are no bends in the casing and steam line from one side to the other, other than this long deflection. In heating up from 60 F to 600 F, the steam line freely expands 8 feet longitudinally in its 2100-foot crossing length. It is not possible to fully restrain the line during heat-up without exceeding the allowable stress limits, so the steam line was installed within a welded steel casing and is free to grow. Initial analysis considered a single 30-inch diameter casing. The design evolved to include a 24-inch diameter inner casing and a 30-inch outer casing. Steam Hydraulics. A simulation of the two phase steam flow was performed to assess slugging and liquid holdup in the channel crossing. The projected flow rate to the first two wells to be drilled on Terminal Island is 50,000 lb/hr, equivalent to 3,000 barrels per day of water. Liquid holdup is low in the downward sloping section, varying from 2% to 9%. Liquid holdup is higher in the upward sloping section, varying from 28% at lower flow rates to 9% at the full output of the cogeneration plant, 465,000 lb/hr. Slugging is not a problem, however, because the slug volumes are relatively small and the velocity is relatively low. P. 163^