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Collaborating Authors
Venezuela
Abstract Since the early 2000s, the exploitation of unconventional reservoirs has become very important to the oil and gas industry because of their high potential source of energy and economic value. Venezuela possesses a world-class hydrocarbon source rock in one of the most prolific hydrocarbon basins in the world, namely the Cretaceous La Luna Formation in the Maracaibo Basin. Outcrop and core samples collected from the northwestern Maracaibo Basin provide the database for this study. A comprehensive multiscale characterization of the samples is undertaken to unravel the stratigraphic properties of the petroleum system. In addition, a geochemical approach is taken to evaluate the prospectivity of the La Luna Formation as an unconventional resource in the Maracaibo Basin. Rock-Eval pyrolysis and biomarker data indicate that the La Luna Formation is dominated by type II kerogen, indicating an oil-prone marine organic matter origin. Total organic carbon values range between 3.85 wt% and 9.10 wt%. Distributions of isoprenoids, steranes, and terpanes including gammacerane and monoaromatic steroid hydrocarbons indicate a hypersaline, marine carbonate anoxic depositional environment. Thermal maturity parameters indicate that most of the cores are currently in the oil window. This combined stratigraphic geochemical study indicates that the La Luna Formation has excellent potential as an unconventional reservoir for oil and gas in the study area.
- Phanerozoic > Cenozoic (1.00)
- Phanerozoic > Mesozoic > Jurassic (0.92)
- Phanerozoic > Mesozoic > Cretaceous > Upper Cretaceous (0.67)
- South America > Venezuela (0.99)
- South America > Colombia > Middle Magdalena Basin > La Luna Shale Formation (0.99)
- South America > Colombia > Aguardiente Formation (0.99)
- (17 more...)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale gas (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
- Reservoir Description and Dynamics > Fluid Characterization > Geochemical characterization (1.00)
Abstract Since the early 2000s, the exploitation of unconventional reservoirs has become very important to the oil and gas industry because of their high potential source of energy and economic value. Venezuela possesses a world-class hydrocarbon source rock in one of the most prolific hydrocarbon basins in the world, namely the Cretaceous La Luna Formation in the Maracaibo Basin. Outcrop and core samples collected from the northwestern Maracaibo Basin provide the database for this study. A comprehensive multiscale characterization of the samples is undertaken to unravel the stratigraphic properties of the petroleum system. In addition, a geochemical approach is taken to evaluate the prospectivity of the La Luna Formation as an unconventional resource in the Maracaibo Basin. Rock-Eval pyrolysis and biomarker data indicate that the La Luna Formation is dominated by type II kerogen, indicating an oil-prone marine organic matter origin. Total organic carbon values range between 3.85 wt% and 9.10 wt%. Distributions of isoprenoids, steranes, and terpanes including gammacerane and monoaromatic steroid hydrocarbons indicate a hypersaline, marine carbonate anoxic depositional environment. Thermal maturity parameters indicate that most of the cores are currently in the oil window. This combined stratigraphic geochemical study indicates that the La Luna Formation has excellent potential as an unconventional reservoir for oil and gas in the study area.
- Phanerozoic > Cenozoic (1.00)
- Phanerozoic > Mesozoic > Jurassic (0.92)
- Phanerozoic > Mesozoic > Cretaceous > Upper Cretaceous (0.67)
- South America > Venezuela (0.99)
- South America > Colombia > Middle Magdalena Basin > La Luna Shale Formation (0.99)
- South America > Colombia > Aguardiente Formation (0.99)
- (17 more...)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale gas (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
- Reservoir Description and Dynamics > Fluid Characterization > Geochemical characterization (1.00)
ABSTRACT: There is an interesting discussion amongst experts about the term discontinuity in the geomechanical rock mass classification for subsurface works applications. This definition, covers the formational planes, like bedding planes and foliation planes, moving fractures and the joints. Using the finite element program, the influence of the rock mass zoning on the stability results and on the dimensions of the required reinforcement were analyzed. The stress relaxation method was considered, defining the characteristic curves for the rock and for the reinforcement. A comparative analysis of the impact on the reinforcement costs is shown when compared with non-zoning model. The proposal is presented to avoid the term discontinuity and to differentiate the real geological structures that affect the rock mass, planes of large continuity, stratification and foliation, from the joints, defined as non-moving fractures whose extension and frequency depend on the changes of the stress state of the rock mass. INTRODUCTION According to the International Society for Rock Mechanics and Rock Engineering (ISRM), discontinuity is a general term denoting any separation in a rock mass having zero or low tensile strength. It is the collective term for most types of joints, weak bedding planes, weak schistocity planes, weakness zones, and faults (Brown, 1981). The previous definition involves several terms, covering the formational planes, no displacement fractures or joints, and moving fractures, mostly with different mechanical behaviors. This diversity hinders the correct application of terms in the rock mass engineering classification and also affect the numerical analysis on rock mechanics, this has led to errors in rock mass evaluation worldwide, with significant cost overruns but with a high safety factor (Naime & García, 2022, 2023). In the rock engineering classification, it's important to separate the formational planes, such as bedding planes and foliation planes, from the joints, which are formed due to mechanical effects. Joints should not be considered as fixed patterns; they are non-moving fractures whose orientation and development depend on the variations of the stress state.
An Alternative Coiled Tubing Solution to Access Isolated Reserves Below Two Ball Valves in the Columbus Basin of Trinidad & Tobago
Mammadli, R. (BP, Houston, Texas, USA) | Adilov, R. (BP, Houston, Texas, USA) | Ramkissoon, A. (BP, Houston, Texas, USA) | Hosein, N. (Tucker Energy Services, Port of Spain, Trinidad and Tobago) | Friedli, J. (Tucker Energy Services, Port of Spain, Trinidad and Tobago) | Holder, D. (Thru Tubing Solutions, Newcastle, Oklahoma, USA)
Abstract The Well A in the Columbus basin of Trinidad & Tobago was completed with a dual selective Cased Hole Gravel Pack. The completion included two ball valves and multiple sliding sleeves to isolate zone A from zone B. At the end of the completion phase, multiple wireline attempts were made to shift open the two ball valves without success. The well was put on production from the upper Zone A only while lower Zone B was isolated with two closed ball valves. This scope was to open the two ball valves to regain access to the reserves in Zone B and to isolate Zone A by closing the sliding sleeves. After numerous wireline attempts to gain access to Zone A via electricline clean out, shifting, and milling tools, coil tubing was selected as an alternate conveyance method to shift close sliding sleeves and open both ball valves. The attempt to close the sliding sleeve and shift open the ball valve with coiled tubing was unsuccessful. The decision was to mill the ball valve with differential pressure creating upward force on milling BHA when milling the ball valves. The initial attempt to close the sliding sleeves with coiled tubing was unsuccessful with one sleeve remaining in communication with Zone A. The top ball valve was milled successfully with a 2.65" tapered bit in ∼4.5 hrs and drifted successfully multiple times using the same toolstring. Pressure behavior confirmed that the bottom ball valve remained fully closed. A 2.5" bit was then run and milled on for ∼8 hrs. with no further progress. A second run was made with a new tapered 2.5" bit and successfully gained access to Zone B. The size of the milled hole estimated on the bottom valve was 1.76". Analysis revealed that the 1.76" restriction at the bottom valve would allow the well to produce at its full well capacity. After successfully gaining access to Zone B, the open sliding sleeve in Zone A was isolated with a straddle packer. The unique achievement was to mill two closed ball valves as part of a single operation. Being unable to shift close a Zone A sliding sleeve created cross-flow conditions in the well throughout the milling of the bottom ball valve. This introduced challenges to run through the milled top ball valve and progress the milling of the second ball valve with differential pressure. As a result, the second ball valve was milled partially, and the straddle packer was installed across the Zone A leaking sliding sleeve with the cross flow. Therefore, this job was a unique experience in the field that had important leanings that are applicable across the industry.
- North America > United States (1.00)
- South America > Venezuela > North Atlantic Ocean (0.61)
- North America > Trinidad and Tobago > Trinidad > North Atlantic Ocean (0.61)
- Well Completion > Completion Monitoring Systems/Intelligent Wells (1.00)
- Well Completion > Completion Installation and Operations > Coiled tubing operations (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
- Production and Well Operations > Well Intervention (1.00)
Historical Cement Packer Case Study from Trinidad & Tobago Columbus Basin
Mammadli, R. (BP, Houston, Texas, USA) | Adilov, R. (BP, Houston, Texas, USA) | Bassie, Y. (BP, Houston, Texas, USA) | Rasmine, M. (Tucker Energy Services, Port of Spain, Trinidad and Tobago) | Hosein, N. (Tucker Energy Services, Port of Spain, Trinidad and Tobago) | Somai, J. (Tucker Energy Services, Port of Spain, Trinidad and Tobago) | Bruce, T. (Interwell, Houston, Texas, USA)
Abstract Historically, in the Columbus basin offshore Trinidad and Tobago small pool reserves are left behind the casing above the existing production packer. A low-cost alternative to an expensive rig workover was required to develop these trapped reserves. As a solution to this challenge, coiled tubing up-hole cement packer re-completion was developed and advanced during the last 10 years. Several well candidates were chosen to trial this method in the region. This paper will discuss the learnings and challenges faced during the execution and how the team applied these learnings for the next candidate selection. Extensive data has been gathered from previous cement packer jobs and evaluated to establish the best practices and understand the key failure mechanisms. Based on the learnings, a candidate well was selected for up-hole recompletion. One of the key learnings from this exercise suggested the importance of well deviation to the success of cement packer jobs. Numerous failed well cement packers experienced contamination and channeling on 40 deg and higher deviation. It was identified that extending the top of the cement packer to the vertical section of the well was crucial for the success of the job. Extensive software modeling and lab testing related to the first-time use of a MgO-based expansive agent were performed to conduct the sensitivities around the height of cement in the annulus, and displacement rate to optimize the displacement efficiency. The analysis was performed to evaluate if the use of different cement retainer types and setting depth contributed to the success of the results. The candidate well delivered planned objectives efficiently and within budget. The cement packer was placed above the zone of interest and logging was performed to confirm the quality of cement bonding. Cement displacement software modeling assisted in designing the pump rates to achieve the best results. Despite the operational challenges which resulted in setting the cement retainer shallower than the intended depth, ~500ft of uncontaminated cement with ~2200 psi compressive strength was attained. Even though the plan of bringing the cement to the vertical section was not achieved during the execution, the required cement packer height was not compromised. Perforations then were made, and ceramic sand screens were installed to prevent sand production. Cement packers are not new to the industry. However, notable learnings were obtained from the Trinidad & Tobago region that integrates the combination of Gas lift mandrels, control lines, operational challenges and limitations. Incorporating previous learnings, cement lab testing, software simulation models, and the use of expanding agents, were the main contributors to the success of this job.
- South America > Venezuela > North Atlantic Ocean (0.61)
- North America > Trinidad and Tobago > Trinidad > North Atlantic Ocean (0.61)
Trinidad Prime Minister Keith Rowley said supermajor Shell has given financial approval for the Manatee field development project offshore Trinidad and Tobago, according to Reuters. The Manatee field is part of the cross-border Loran-Manatee discovery, shared by Trinidad and Venezuela. The field is believed to hold around 10 Tcf of natural gas, with 7.3 Tcf on Venezuela's side and the remaining 2.7 Tcf on Trinidad's side. The countries negotiated for years to jointly develop the reservoir and signed preliminary agreements, but a final agreement had not been completed by the time the US imposed sanctions in 2019 on Venezuela's energy industry, limiting its partnerships and business with foreign companies. Venezuela President Nicolás Maduro later agreed to allow Trinidad to independently develop its portion of the massive natural gas field.
- South America > Venezuela (1.00)
- North America > United States > Gulf of Mexico > Central GOM (0.53)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > South America Government > Venezuela Government (0.62)
Continuous monitoring of electrical submersible pumps (ESPs) ensures optimal working operating conditions and avoids deferred oil production. With the increased population of ESPs deployed worldwide, a comprehensive alarm triggering system is at the center of modern oilfield production surveillance systems. In this paper, a data-driven ESP smart alarm suite, integrated with a virtual flowmeter (VFM) deployed on the Edge, is presented with testing results and field applications for effectiveness demonstration. The overall Smart Alarm Suite consists of eight different alarms, each targeting a specific potential suboptimal pump working condition. For three alarms, a data-driven approach is adopted with the application of multiple classical machine learning models such as logistics regression, K-Means clustering, continuous linear regression, etc.
- Instructional Material > Course Syllabus & Notes (0.37)
- Instructional Material > Online (0.35)
- Energy > Oil & Gas > Upstream (1.00)
- Education > Educational Technology > Educational Software > Computer Based Training (0.89)
Today, if one looks out at the vast offshore oil fields of the Gulf of Mexico, Venezuela, Brazil, the North Sea, West Africa, and the Arabian Gulf, it is hard to imagine that, at some point, all that mass oil and gas production for our energy and transport needs will come to an end. So, what will take its place? We have dabbled with nuclear power, but that is potentially more harmful than a carbon-based energy source and, in most quarters, definitely less popular. Hydroelectric power stations were once the darling of the alternative energy brigade of the mid-20th century, but flooding fertile valleys, displacing whole populations, and adversely affecting fauna and flora has cost that option its environmentally friendly status. Besides, demands on fresh water in many parts of the world have added another dimension to the issue.
- North America > United States (0.38)
- North America > Mexico (0.27)
- South America > Venezuela (0.25)
- (7 more...)
- Europe > United Kingdom > North Sea (0.89)
- Europe > Norway > North Sea (0.89)
- Europe > Netherlands > North Sea (0.89)
- (2 more...)
Artificial lift is a key component in oil and gas production. Most of the unconventional wells end up in some form of Artificial lift in 2-3 years of their life. Managing artificial lift performance/ failure becomes very crucial as it is one of the major downtime attributes. Due to rapid decline of the pressure and the flow rates in these wells, understanding the well performance becomes key for optimization of the artificial lift. A process can be applied to cover the life cycle of the Artificial lift which includes selection or re-selection, redesign and proactive management of the lift system.
- South America > Venezuela (0.19)
- North America > Mexico (0.17)
- Instructional Material > Course Syllabus & Notes (0.36)
- Instructional Material > Online (0.34)
- Energy > Oil & Gas > Upstream (1.00)
- Education > Educational Technology > Educational Software > Computer Based Training (0.89)
Strategy to Manage Mature Oilfields with Renewable Energies
Quintero, E. (TecnoPetrol, Ingenieros Consultores, Maracaibo, Zulia, Venezuela) | Valdirio, J. (PDVSA, Caracas, Distrito Capital, Venezuela) | Bastardo, J. (PETROZAMORA, Lagunillas, Zulia, Venezuela) | Huerta, V. (Universidad Nacional de Ingeniería, Lima, Perú) | Lorbes, H. (Instituto Universitario Politécnico Santiago Mariño IUPSM)
Abstract In the case of the Venezuelan Maracaibo Lake Basin, the existence of mature represents a good opportunity to recover them using renewable energy, even worldwide exploration efforts become are almost inaccessible and environmentally sensitive places. Therefore, many companies have shifted his strategies to revitalize mature fields, increase their recovery factor and extend their life cycle. This study proposes an integrated approach to revitalize mature fields, but in a sustainable way. by incorporating renewable sources to supply part of the energy field consumption; thus, allowing monetizing more oil (usually used as fuel consumption), and improving asset management by implementing a production monitoring system (based on field automation and remote-control processes). The integrated approach to revitalize mature fields includes the following steps: Reserves management upon best practices recommended in PRMS 2018 and follow up based on performance and sustainability indicators. Artificial lift technologies to optimize production performance. Identification of potential opportunities to substitute fuel consumption with renewable energy sources; incorporated to production optimization, energy efficiency and remote monitoring programs. Implementation of energy transition programs focused on maximizing asset value and improving corporate reputation. It should be noted that Solar and Eolic energy sources were preliminarily identified as the best suited to contribute with revitalization of mature fields, by substituting in between 10 to 15% of fuel consumption; besides this, uncertainty in renewable energy supply, as well as "the state of the art" technologies to extend energy storage should be take into consideration for implementing energy transition programs. In addition, future applications of renewable energy sources in EOR projects may be further investigated considering the benefits in production performance and reservoir management.
- Asia (1.00)
- South America > Venezuela > Zulia > Maracaibo (0.26)