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Tanzania
Equinor, Shell and Exxon Mobil have agreed to a deal with the government of Tanzania that will result in the country's first liquefied natural gas (LNG) export terminal. The deal includes Tanzania's agreement to provide a regulatory framework and a production-sharing agreement and is subject to legal reviews and quality assurance before an expected signing in the coming weeks. The agreement is another crucial step forward for the long-delayed project to develop Tanzania's vast, remote offshore natural gas reserves. Delays in the project were due in part to outstanding regulatory issues. "It paves the way for the series of milestones that need to follow to realize this fantastic LNG opportunity for the country and the world," Equinor's Tanzania Country Manager Unni Fjaer said in a statement to Reuters.
Industry:
- Energy > Oil & Gas > Upstream (1.00)
- Energy > Oil & Gas > Midstream (1.00)
- Government > Regional Government > Africa Government > Tanzania Government (0.88)
SPE Disciplines: Facilities Design, Construction and Operation > Natural Gas Conversion and Storage > Liquified natural gas (LNG) (1.00)
The government of Tanzania has approved construction of the 3.5 billion, 1443-km East Africa Crude Oil Pipeline (EACOP) to export production beginning in 2025 from developments in Lake Albert in northwest Uganda to a facility near Tanzania's port of Tanga on the Indian Ocean. Tanzania's approval of the project on 21 February followed Uganda's move a month ago to issue a license to project operator, EACOP Ltd. Commenting in Tanzania's business media outlet, The Citizen, EACOP Tanzania general manager Wendy Brown said that, now with Tanzania's approval, construction will start once the "ongoing land access process" is finished. Once completed, the EACOP pipeline will be the longest heated pipeline in the world, according to the US Department of Commerce, International Trade Administration (ITA). France's TotalEnergies and the China National Offshore Oil Corporation (CNOOC) declared a final investment decision in February of last year on the project which includes development of oil fields, processing facilities, and an electrically heated pipeline network.
africa government, asia government, china government, citizen, construction, corporation, eacop, flowline corrosion, Lake Albert, longest heated crude pipeline, materials and corrosion, Midstream Oil & Gas, north america government, operator, Pipeline Corrosion, riser corrosion, standard chartered, Tanzania, tanzania government, tanzania greenlight world, Uganda, united states government, Upstream Oil & Gas
Industry:
- Energy > Oil & Gas > Midstream (1.00)
- Energy > Oil & Gas > Upstream (0.94)
- Government > Regional Government > North America Government > United States Government (0.94)
- Government > Regional Government > Asia Government > China Government (0.62)
SPE Disciplines: Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers > Materials and corrosion (0.40)
The government of Tanzania has signed a liquefied natural gas (LNG) framework agreement with the UK's Shell and Norway's Equinor that is expected to kick-start construction of a $30- to $40-billion LNG export terminal to commercialize the country's deepwater offshore gas reserves. The deal signed by the three parties on 11 June is foundational to the Tanzanian government's issuance of a Host Government Agreement (HGA) later this year which will outline the project's technical, commercial, and legal terms, according to Bloomberg. Front-end engineering and design (FEED and pre-FEED) will be completed within 3 years of HGA signing, with a final investment decision targeted in 2025. A 4- to 5-year construction period will follow with a first LNG drop planned by 2029–2030. The plant will be built at the East African nation's southern coastal town of Lindi.
africa government, african nation, agreement, aljazeera, block 2, construction, discovery, equinor, Europe, gas monetization, liquefied natural gas, liquified natural gas, LNG, LNG export, LNG Terminal, Midstream Oil & Gas, Mozambique, operation, resource base, Tanzania, tanzania government, tanzania ink deal, tanzanian government, Upstream Oil & Gas
Industry:
- Energy > Oil & Gas > Upstream (1.00)
- Energy > Oil & Gas > Midstream (1.00)
- Government > Regional Government > Africa Government > Tanzania Government (0.57)
SPE Disciplines: Facilities Design, Construction and Operation > Natural Gas Conversion and Storage > Liquified natural gas (LNG) (1.00)
Abstract Historically, permeability prediction has been a challenge in petrophysical interpretations. As a result, different empirical formulas have been generated in order to assist with permeability prediction. The evolution of Artificial Intelligence (AI) techniques in the industry has led to improvement on permeability prediction from log and core data. The objective of this paper is to determine the reliability of the self-organizing maps (SOM) method in predicting the permeability of the Neocomian sandstone reservoir found in the onshore gas field in South- East Tanzania. Three wells from one natural gas producing field were chosen for this study and one of the wells was used as a blind test well in order to confirm the predictive capacity of the AI technique. The AI technique that was used in the petrophysical interpretation is SOM. The Winland R35 method was used for the creation of eleven (11) hydraulic flow units that were used as calibration in the model of the AI technique. The deterministic petrophysical interpretation was conducted for all wells and the obtained log porosity was stress corrected and used in the multi-line formulae model together with the permeability formulas obtained from the Winland R35 method. The curves obtained from the SOM AI technique were used for calculation and creation of a continuous permeability curve. The performance of the SOM AI technique in predicting permeability of the Neocomian sandstone reservoir was evaluated. The results of predicted permeability from the SOM AI technique was compared against the stress corrected core permeability. The self-organizing maps (SOM) technique produced very good results based on correlation and comparisons between the predicted and stress corrected core permeability. The result showed that the SOM technique has great potential for handling missing curves and was considered to be a reliable method for permeability prediction. Introduction The Songo Songo Gas Field is found in the South-Eastern part of Tanzania, onshore and offshore of the Songo Songo Island in the Rufiji Trough (Figure 1). The Songo Songo Gas Field is located towards the South of the Rufiji Delta. The gas field was discovered in 1974. Natural gas of commercial quantity was encountered in the Cretaceous (Neocomian), shallow to marginal marine sandstones on a fault-block structure. Twelve (12) wells have been drilled to date. The gas Field is currently one of the largest producing gas fields in the East African region.
ai technique, Artificial Intelligence, core permeability, flow in porous media, Fluid Dynamics, gas field, input curve, machine learning, permeability, Permeability prediction, petrophysical interpretation, porosity, rd annual logging symposium, Reservoir Characterization, som method, SOM model, som technique, spwla 63, spwla-2022-0127, Upstream Oil & Gas
Country:
- Africa > Tanzania > Indian Ocean > Songo Songo Island (0.45)
- Africa > Tanzania > Indian Ocean > Nyuni Island (0.44)
Oilfield Places: Africa > Tanzania > Indian Ocean > Songo Songo Island > Ruvuma Basin > Songo-Songo Field > Ruaruke Formation (0.99)
SPE Disciplines:
Geological and Field Justification of Yuzhno-Vyintoyskoye Field Development Process Based on Dynamic Marker Monitoring in Horizontal Wells
Dulkarnaev, Marat (LUKOIL West-Siberia LLC, Povkhneftegaz CCI) | Katashov, Alexander (GEOSPLIT LLC) | Belova, Anna (GEOSPLIT LLC) | Husein, Nadir (GEOSPLIT LLC) | Malyavko, Evgeny (GEOSPLIT LLC) | Saprykina, Kseniya (GEOSPLIT LLC) | Upadhye, Vishwajit (GEOSPLIT LLC) | Semenova, Ekaterina (GEOSPLIT LLC)
Summary Effective management of oil and gas field development is impossible without employing an integrated approach to well and reservoir studies, well interference assessment, and analysis of the reservoir pressure maintenance system effectiveness. To make hard-to-recover reserves development effective, the key objective is to develop and substantiate recommendations for stimulating oil recovery and increasing the oil recovery factor. This paper dwells on a new approach to the geological feasibility study of the field development management and inter-well influence evaluation, which involves predictive modelling. Such an approach implies studying the field geological structure, analysing the current recovery status, dynamic quantum tracer-based production profile surveillance in horizontal wells, as well as using Spearman rank correlation analysis to evaluate the performance of the reservoir pressure maintenance system. The subject reservoir is represented by a series of wedge-shaped Neocomian sandstones that are marked by a complex geological structure, lateral continuity, non-uniform distribution of reservoir rocks, and an extensive water-oil zone. At the moment, the subject field is in a production increase cycle (Dulkarnaev et al., 2020). An integrated approach was used in this study to provide an extra rationale to the starting points of the reservoir pressure maintenance system impact at new drilling sites to improve oil recovery and secure sustainable oil production and the reserve development rate under high uncertainty.
asset and portfolio management, correlation coefficient, Directional Drilling, drilling operation, Drillstem Testing, drillstem/well testing, dynamic marker monitoring, Effectiveness, enhanced recovery, field feasibility study, Field Justification, horizontal well, Offshore Technology Conference, production control, production monitoring, recommendation, Reservoir Characterization, Reservoir Surveillance, Spearman, system effectiveness, Upstream Oil & Gas, water content, yuzhno-vyintoyskoye field development process
Country:
- North America > United States (0.29)
- Africa > Tanzania > Indian Ocean > Nyuni Island (0.24)
SPE Disciplines:
Geological and Field Feasibility Study of Field Development Management Using Marker-Based Production Profiling Surveillance in Horizontal Wells: The Case Study of the Yuzhno-Vyintoiskoye Field
Dulkarnaev, Marat Rafailevich (Povkhneftegaz Lukoil – West Siberia LLC) | Kotenev, Yuri Alexeyevich (Ufa State Petroleum Technological University) | Sultanov, Shamil Khanifovich (Ufa State Petroleum Technological University) | Chibisov, Alexander Viacheslavovich (Ufa State Petroleum Technological University) | Chudinova, Daria Yurievna (Ufa State Petroleum Technological University) | Katashov, Alexander Yurievich (GeoSplit LLC) | Malyavko, Evgeny Alexandrovich (GeoSplit LLC) | Buyanov, Anton Vitalievich (GeoSplit LLC) | Semyonova, Ekaterina Evgenievna (GeoSplit LLC) | Gorbokonenko, Oksana Alexandrovna (GeoSplit LLC)
In pursuit of efficient oil and gas field development, including hard-to-recover reserves, the key objective is to develop and provide the rationale for oil recovery improvement recommendations. This paper presents the results of the use of the workflow process for optimized field development at two field clusters of the Yuzhno-Vyintoiskoye field using geological and reservoir modelling and dynamic marker-based flow production surveillance in producing horizontal wells. The target reservoir of the Yuzhno-Vyntoiskoye deposit is represented by a series of wedge-shaped Neocomian sandstones. Sand bodies typically have a complex geological structure, lateral continuity and a complex distribution of reservoir rocks. Reservoir beds are characterised by low thickness and permeability. The pay zone of the section is a highly heterogeneous formation, which is manifested through vertical variability of the lithological type of reservoir rocks, lithological substitutions, and the high clay content of reservoirs. The target reservoir of the Yuzhno-Vyintoiskoye field is marked by an extensive water-oil zone with highly variable water saturation. According to paleogeographic data, the reservoir was formed in shallow marine settings. Sand deposits are represented by regressive cyclites that are typical for the progressing coastal shallow water (Dulkarnaev et al., 2020). Currently, the reservoir is in production increase cycle. That is why an integrated approach is used in this work to provide a further rationale and creation of the starting points of the reservoir pressure maintenance system impact at new drilling fields to improve oil recovery and secure sustainable oil production and the reserve development rate under high uncertainty.
asset and portfolio management, decision-making, Directional Drilling, drilling operation, Drillstem Testing, drillstem/well testing, Effectiveness, enhanced recovery, field development management, field feasibility study, flow communication, flow pathway, horizontal well, injection well, marker-based production profiling surveillance, Producing Well, production control, production monitoring, recommendation, Reservoir Characterization, Reservoir Surveillance, subject field, system effectiveness, target reservoir, Upstream Oil & Gas, water content, waterflooding, yuzhno-vyintoiskoye field
SPE Disciplines:
Total, CNOOC, and the national oil companies of Uganda and Tanzania have green lighted their $5.1-billion Lake Albert development to tap more than a billion barrels of Ugandan crude and ship it by pipeline across east Africa to Tanzania and export markets beyond. Participants in the signing ceremony Sunday in Entebbe included Uganda's President Yoweri Museveni; Samia Suluhu Hassan, president of Tanzania; Total Chairman and CEO, Patrick Pouyanné; and representatives of China National Offshore Oil Corporation (CNOOC), Uganda National Oil Company (UNOC), and Tanzania Petroleum Development Corporation (TPDC), according to a Total press release. The Lake Albert development encompasses Tilenga and Kingfisher upstream oil projects in Uganda and the construction of the East African Crude Oil Pipeline (EACOP) in Uganda and Tanzania. Total operates the Tilenga project, while CNOOC operates the Kingfisher project. Together, these two projects are expected to deliver a combined production of 230,000 B/D at plateau, according to Total.
Industry:
- Government > Regional Government > Asia Government > China Government (1.00)
- Energy > Oil & Gas > Upstream (1.00)
SPE Disciplines: Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers (0.57)
The Journal of Petroleum Technology, the Society of Petroleum Engineers' flagship magazine, presents authoritative briefs and features on technology advancements in exploration and production, oil and gas industry issues, and news about SPE and its members.
ABSTRACT The subsea gas development of Block 2 offshore Tanzania described in this paper is characterized by water depths of up to 2600 meters and tie-back distance to shore of around 100 km. The seabed consists of deep, large scale canyons and steep inclinations towards shore. The reservoir fluids contain very little condensate and the pipeline flow is typically low liquid loading conditions at high water fractions. Extensive studies have been carried out during the last 5 years by the Equinor Tanzania Gas Development Project to verify multiphase flow models for our flow conditions. The key focus of work presented at the MPT 2015 was related to liquid accumulation. However, this work also revealed that frictional pressure drop increases significantly with high water fractions, existing flow models severely under predicts frictional pressure drop at high water fractions, and they are not able to predict the effect of water fraction on the frictional pressure drop little experimental data exist for such conditions (low liquid loading three phase flow at high superficial gas velocities). The work and results related to frictional pressure drop in vertical flow were presented at the MPT 2017, while the key focus of the presentations this time is related to frictional pressure drop in near horizontal flow in low liquid loading at high water fractions. To support model development and model verification experiments have been conducted during 2017 and 2018 in both 8 and 12 inch near horizontal pipes at the Tiller test facility in Norway, while model development and model verification studies have been carried out with both Schlumberger (OLGA) and SINTEF (Ledaflow). This presentation gives an overview of the Tanzania deep water gas development with focus on the flow assurance challenges relates to the subsea to beach concept and the background, motivation for the conducted work, while the experiments (SINTEF)", the model development and verification (Schlumberger and SINTEF) are presented in detail in separate presentations.
17th international conference, accumulation, drilling operation, equation of state, experiment, frictional pressure drop, high water fraction, holm, inclination, infield flow line, international conference, liquid accumulation, liquid loading, Multiphase Production Technology, Norway, pipeline, superficial gas velocity, Upstream Oil & Gas
Country:
- Africa > Tanzania (1.00)
- Europe (0.72)
- North America > United States > Texas (0.68)
SPE Disciplines:
ABSTRACT A comprehensive three-phase flow campaign, funded by Equinor as part of the Tanzania gas field development project [1] [2] [3], was carried out in the SINTEF Large Scale Loop at Tiller in 2017–2018. The experiments were conducted in a 94 meter long 8" pipe, with 2.5° inclination at 60 bar nominal system pressure, using nitrogen, Exxsol D60 and water with and without glycerol. The motivation for performing this study was to support model development targeted towards reducing prediction uncertainty for high-rate low liquid loading conditions. Specifically, the experiments were conducted at conditions that to a certain extent matched those expected during plateau production for the subsea gas development in Block 2 offshore Tanzania. One of the key concerns was that the presence of oil, water and MEG increases the frictional pressure drop more than current multiphase models predict. The focus of the work was on gas dominated three-phase flows, with low liquid rates (USL=0.0001-0.1 m/s), and mainly high gas rates (USG=4-14 m/s). The effect of the water viscosity was investigated by mixing glycerol (70–74%) with the water, and conducting experiments at different temperatures, yielding water viscosities in the range 14–42 cP. The aim of the experimental campaign was to produce experimental data relevant for modelling two- and three-phase low liquid loading flows at high gas rates. Earlier experiments [4] had revealed that the pressure drop was significantly higher in three-phase flows compared to two-phase flows, and the current experiments were conducted to investigate this phenomenon more thoroughly. In this paper we provide an overview of the experimental campaign, and we show some of the key results. Some of the main findings from the experiments were: The pressure drop depends significantly on the water cut. In general, the pressure drop increases with water cut, reaching a maximum value at around WC=80%, after which the pressure drop decreases again. For three-phase experiments with tap water, the maximum pressure drop was typically 20–40% higher than for two-phase gas-oil, while with the water/glycerol mixture, the maximum pressure drop could be up to 80–100% higher than for the gas-oil system. For high water cuts, the frictional pressure drop increases with increasing water viscosity, while for low water cuts, the frictional pressure drop is independent of the water properties.
average water fraction, bhr group mpt2019, conformance improvement, drilling operation, droplet, enhanced recovery, experiment, explanation, Fluid Dynamics, fluid system, fraction, glycerol, maximum pressure drop, multiphase flow, normalized pressure drop, pipe, pressure drop, pressure drop increase, production control, production logging, production monitoring, Reservoir Surveillance, three-phase flow, Upstream Oil & Gas, usl 0, viscosity, water cut, water droplet, water fraction, water viscosity
Country:
- North America > United States (0.68)
- Africa > Tanzania (0.46)
SPE Disciplines:
- Well Drilling > Drilling Operations (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Multiphase flow (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Conformance improvement (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Production logging (1.00)
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