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Summary Atlanta Field is a post-salt heavy-oil field located 185 km off the city of Rio de Janeiro, in Santos Basin, Brazil, at a water depth of approximately 1550 m. Atlanta, however, is not just another ultradeepwater heavy-oil field. Several additional challenges had to be overcome for its development, such as low reservoir overburden (800m), highly unconsolidated sandstone reservoir (36% porosity and 5,000 md permeability), heavy and viscous crude flow assurance (14 °API and 228 cp at initial reservoir conditions), high-naphthenic-acidity oil [total acid number (TAN) 10mg KOH/g], high-power artificial-lift pumping-systemrequirement (1,600 hp), and complex-topside crude facilities. The development of Atlanta Field was phased in two stages: an early production system (EPS), which is expected to last from four to five years and comprises three horizontal production wells; and a definitive production system (DPS), which will add nine wells to complete the development plan with 12 horizontal producers. The first two EPS wells were successfully constructed and tested during 2013 and 2014, proving the feasibility of surpassing the great challenges imposed by the field’s unique environment and enabling the beginning of the production phase of the field. The first oil occurred in May 2018 with these two wells producing to the floating production, storage, and offloading unit (FPSO) Petrojarl I. The third and last producer of the EPS was constructed in 2019 and began operation in June of the same year. More than five million barrels of oil were already produced to date. Marsili et al. (2015) described in detail the exploration and development phases of Atlanta Field, focusing on their challenges, the overcoming process, and solutions adopted. This current work intends to present an updated review of the paper, providing the most recent information related to the project with a subsequent focus on the production phase findings and results. Among others, the initial prediction and expectations will be compared with actual field performance. For all milestones achieved, the Atlanta project is considered a great success so far and a benchmark for the industry in this harsh and adverse environment.
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean (1.00)
- North America > United States > Arkansas > Columbia County (1.00)
- South America > Brazil > Rio de Janeiro > Rio de Janeiro (0.68)
- Geology > Petroleum Play Type > Unconventional Play > Heavy Oil Play (1.00)
- Geology > Structural Geology (0.88)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.68)
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying > Seismic Processing (0.67)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Completion > Sand Control (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Oil sand, oil shale, bitumen (1.00)
- (11 more...)
Figure 1.1 illustrates reservoir management processes. The processes are divided into those stewarded by the reservoir management team (RMT) and those guided by the supervisors and managers associated with reservoir management who comprise the reservoir management leadership team (RMLT). The arrows in the RMT box show work flow and how data and opportunities are captured.
- Asia (1.00)
- South America (0.67)
- North America > United States > Texas (0.46)
- Europe > United Kingdom > North Sea (0.28)
- Geology > Sedimentary Geology > Depositional Environment (1.00)
- Geology > Structural Geology > Fault (0.93)
- Geology > Geological Subdiscipline > Stratigraphy (0.93)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.48)
- Geophysics > Seismic Surveying (1.00)
- Geophysics > Borehole Geophysics (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Water & Waste Management > Water Management > Lifecycle > Disposal/Injection (0.47)
- Europe > United Kingdom > North Sea > Northern North Sea > East Shetland Basin > Block 211/7a > Magnus Field > Kimmeridge Formation > Magnus Formation (0.99)
- Europe > United Kingdom > North Sea > Northern North Sea > East Shetland Basin > Block 211/7a > Magnus Field > Kimmeridge Formation > Lower Kimmeridge Clay Formation (0.99)
- Europe > United Kingdom > North Sea > Northern North Sea > East Shetland Basin > Block 211/29 > Brent Field (0.99)
- (15 more...)
- Well Drilling > Well Planning (1.00)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Completion > Completion Installation and Operations (1.00)
- (23 more...)
Any reservoir simulator consists of n m equations for each of N active gridblocks comprising the reservoir. These equations represent conservation of mass of each ofn components in each gridblock over a timestep Δt from tn to tn 1 . The firstn (primary) equations simply express conservation of mass for each of n components such as oil, gas, methane, CO2, and water, denoted by subscript I 1,2,…,n. In the thermal case, one of the "components" is energy and its equation expresses conservation of energy. An additional m (secondary or constraint) equations express constraints such as equal fugacities of each component in all phases where it is present, and the volume balanceSw So Sg Ssolid 1.0, whereS solid represents any immobile phase such as precipitated solid salt or coke. There must be n m variables (unknowns) corresponding to these n m equations. For example, consider the isothermal, three-phase, compositional case with all components present in all three phases.
- Europe > United Kingdom (1.00)
- Europe > Norway (1.00)
- North America > United States > Texas (0.94)
- (2 more...)
- Geology > Structural Geology > Fault (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.67)
- Geophysics > Seismic Surveying (0.67)
- Geophysics > Time-Lapse Surveying > Time-Lapse Seismic Surveying (0.67)
- South America > Argentina > Patagonia > Golfo San Jorge Basin (0.99)
- North America > United States > California > San Joaquin Basin > Lost Hills Field (0.99)
- North America > United States > Alaska > North Slope Basin > Prudhoe Bay Field (0.99)
- (20 more...)
- Well Drilling > Wellbore Design > Wellbore integrity (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Gas-condensate reservoirs (1.00)
- Reservoir Description and Dynamics > Reservoir Simulation > Streamline simulation (1.00)
- (21 more...)
Concept Baseline for the Development of a Major Complex Field in Eastern Siberia using Flow Simulation
Levanov, A. N. (Tyumen Petroleum Research Center) | Belyansky, V. Y. (Tyumen Petroleum Research Center) | Volkov, I. A. (Tyumen Petroleum Research Center) | Anuriev, D. A. (Tyumen Petroleum Research Center) | Grinchenko, V. A. (Rosneft) | Neftegazodobycha, Taas-Yuryakh (Rosneft) | Musabirov, T. R. (Rosneft)
Abstract A case study of Srednebotuobinskoye Field, the oil deposits of which are confined to gas-oil-water and oil-water zones, describes the evolution of design decisions for development after the first year of asset operation. The first production data showed the need for separate solutions for under-gas-cap and water-oil zones, and the formation of a new field development concept, and their justification was the purpose of the work the results of which are shown in this paper. The difference with the previously performed work lies in the fact that development decisions were made based on the results of multiple runs on a variety of complex flow simulation models - fine-cellular and full-scale. The outcome of the study was the creation of a new development concept which provides different design solutions for under-gas-cap and water-oil zones. The value of the work lies in the fact that the decisions involve different oil displacement processes in different parts of deposits, which affects the oil recovery rate and as a consequence the whole field development and infrastructure complex.
- Europe (0.93)
- Asia > Russia > Siberian Federal District > Krasnoyarsk Krai (0.46)
- Asia > Russia > Far Eastern Federal District > Sakha Republic (0.35)
- Asia > Russia > Ural Federal District > Khanty-Mansi Autonomous Okrug (0.28)
- Europe > Norway > North Sea > Northern North Sea > North Viking Graben > PL 054 > Block 31/6 > Troll Field > Sognefjord Formation (0.99)
- Europe > Norway > North Sea > Northern North Sea > North Viking Graben > PL 054 > Block 31/6 > Troll Field > Heather Formation (0.99)
- Europe > Norway > North Sea > Northern North Sea > North Viking Graben > PL 054 > Block 31/6 > Troll Field > Fensfjord Formation (0.99)
- (29 more...)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Reservoir Description and Dynamics > Reservoir Simulation (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- (6 more...)
Petroleum reservoir management is a dynamic process that recognizes the uncertainties in reservoir performance resulting from our inability to fully characterize reservoirs and flow processes. It seeks to mitigate the effects of these uncertainties by optimizing reservoir performance through a systematic application of integrated, multidisciplinary technologies. It approaches reservoir operation and control as a system, rather than as a set of disconnected functions. As such, it is a strategy for applying multiple technologies in an optimal way to achieve synergy. Need for improved recovery projects * 4.3.4 Large models * 4.5 Implement and operate * 4.5.1 Implementation plan * 4.5.2
- Europe > Norway > North Sea > Northern North Sea > North Viking Graben > PL 104 > Block 30/9 > Oseberg Field > Tarbert Formation (0.99)
- Europe > Norway > North Sea > Northern North Sea > North Viking Graben > PL 104 > Block 30/9 > Oseberg Field > Oseberg Formation (0.99)
- Europe > Norway > North Sea > Northern North Sea > North Viking Graben > PL 079 > Block 30/9 > Oseberg Field > Tarbert Formation (0.99)
- (3 more...)
- Reservoir Description and Dynamics > Reservoir Simulation (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Drillstem/well testing (1.00)
- (7 more...)
- Information Technology > Knowledge Management (0.40)
- Information Technology > Communications > Collaboration (0.40)
Petroleum reservoir management is a dynamic process that recognizes the uncertainties in reservoir performance resulting from our inability to fully characterize reservoirs and flow processes. It seeks to mitigate the effects of these uncertainties by optimizing reservoir performance through a systematic application of integrated, multidisciplinary technologies. It approaches reservoir operation and control as a system, rather than as a set of disconnected functions. As such, it is a strategy for applying multiple technologies in an optimal way to achieve synergy. Need for improved recovery projects * 4.3.4 Large models * 4.5 Implement and operate * 4.5.1 Implementation plan * 4.5.2
- Europe > Norway > North Sea > Northern North Sea > North Viking Graben > PL 104 > Block 30/9 > Oseberg Field > Tarbert Formation (0.99)
- Europe > Norway > North Sea > Northern North Sea > North Viking Graben > PL 104 > Block 30/9 > Oseberg Field > Oseberg Formation (0.99)
- Europe > Norway > North Sea > Northern North Sea > North Viking Graben > PL 079 > Block 30/9 > Oseberg Field > Tarbert Formation (0.99)
- (3 more...)
- Reservoir Description and Dynamics > Reservoir Simulation (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Drillstem/well testing (1.00)
- (7 more...)
- Information Technology > Knowledge Management (0.40)
- Information Technology > Communications > Collaboration (0.40)
Development Optimisation and Application in a Giant Carbonate Oilfield Under Low Remuneration Fee, Y Oilfield in Iraq
Hu, Dandan (Research Inst. of Petroleum Exploration and Development, PetroChina) | Guo, Rui (Research Inst. of Petroleum Exploration and Development, PetroChina) | Feng, Mingsheng (Research Inst. of Petroleum Exploration and Development, PetroChina) | Wang, Liangshan (Research Inst. of Petroleum Exploration and Development, PetroChina) | Wei, Liang (Research Inst. of Petroleum Exploration and Development, PetroChina) | Wu, Yuanbing (Greatwall Drilling Co., CNPC) | Luo, Yupeng (Jidong Oilfield Co., CNPC) | Tian, Ping (Iraqi Co., CNPC)
Abstract Y is a giant carbonate oilfield with low permeability and mid-high porosity, of which the characteristic is extensive plane distribution and many series of oil-zones in the longitudinal direction. The service contract required a large scale capacity construction with nearly 30 million ton and long stable production period above 13 years, but provided a low remuneration fee with only 1.4$/bbl. Full oilfield integrated optimization is crucial to achieve high effective development and enhance economic benefit. In this paper, the procedure of research on integrated development optimization was elaborated. The paper established new productivity model with oil-water two phase to accurately evaluate oil well productivity. Depletion mode and zones combination were demonstrated and optimized through core experiments and numerical simulation. The sensitivity studies of well types, well patterns and well spacings were carried out through modelling and empirical formula method. Multifactor analysis was completed with surface engineering and external oil-gas transportation capacity as important factors, and development strategy of rapid productivity construction and rolling development is put forward. Depletion plan for each reservoir has been also optimized based on full reservoir simulation modelling. The recommended depletion plan has been implemented in the oilfield development, of which productivity coincidence rate was nearly 100%, first stage productivity capacity with 5 million ton has been set up in 2012, and IRR increased from 9% to above 13%. Introduction Y is a giant carbonate oilfield in Iraq, with huge oil area, massive geological reserves, multiple zones in the vertical direction, varied characteristics in the lateral direction and high well productivity. These carbonate reservoirs have low natural energy and reservoir pressure declines rapidly when depletion drive is adopted, resulting in low recovery. Development optimization is needed, proper measures should be taken to supplement energy, and economic and effective technical plan should be proposed to improve the production rate within contract period and get a high and stable production. Zones are combined and optimal development mode is selected according to the policy in host country of resources and requirement in production and services contract. The type of well and well pattern is determined based on the underground and surface is integrated and optimized. The goal is to maximize the potential of each reservoir and achieve overall development of the oilfield and improve the production rapidly. The key point in economic and efficient development is to improve well production significantly and keep the well production stable for a relative long period of time, with a low profit of 1.4$/bbld in the contract. In order to improve production by dozens of million tons and get a stable production in the long term in Y oilfield, this paper optimizes the overall development plan to minimize the early investment and to achieve progressive development of the oilfiled and maximize the economic benefit. The production of 5 million tons in the first stage, which was started ahead of schedule, and the productivity of 10 million tons, which was achieved in the second stage, provides references and instruction on how to develop similar huge carbonate oilfield.
- North America > United States (0.94)
- Asia > Middle East > Iraq (0.71)
- Asia > China > Bohai Bay > Bohai Basin > Jidong Nanpu Field (0.99)
- Asia > Middle East > Qatar > Arabian Gulf > Arabian Basin > Arabian Gulf Basin > Block 6 > Al Khalij Field > Mishrif Formation (0.98)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Reservoir Description and Dynamics > Reservoir Simulation (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- (5 more...)
Development History Case of a Major Oil-Gas-Condensate Field in a New Province
Grinchenko, V. A. (Tyumen Petroleum Research Centre) | Anuryev, D. A. (Tyumen Petroleum Research Centre) | Miroshnichenko, A. V. (Tyumen Petroleum Research Centre) | Gordeev, Y. I. (VerkhnechoskNefteGas) | Lazeev, A. N. (NK Rosneft)
Eastern Siberia is currently an insufficiently explored area with complex conditions, on the other hand it has a high hydrocarbon potential. A number of oil and gas fields have been discovered in the region already. Vigorous exploration and appraisal works are performed there. However, bringing new fields into development is impeded by multiple factors including complex natural climatic conditions, insufficient exploration of the region, significant distances between fields within the area, absence of transport and industrial infrastructure, and finally complex geologic-and-physical reservoir characteristics. All above factors require nonstandard approaches to field development design and engineering solutions for effective oil and gas recovery.
- Europe (0.93)
- Asia > Russia > Siberian Federal District > Irkutsk Oblast > Kataganskiy District (0.15)
- Europe > United Kingdom > North Sea > Southern North Sea > Southern Gas Basin > Sole Pit Basin > Block 49/21 > V-Fields > Vulcan Formation (0.99)
- Europe > United Kingdom > North Sea > Southern North Sea > Southern Gas Basin > Sole Pit Basin > Block 49/16 > V-Fields > Vulcan Formation (0.99)
- Europe > United Kingdom > North Sea > Southern North Sea > Southern Gas Basin > Sole Pit Basin > Block 48/25b > V-Fields > Vulcan Formation (0.99)
- (2 more...)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Gas-condensate reservoirs (1.00)
- Reservoir Description and Dynamics > Reservoir Simulation (1.00)
- (7 more...)
- Information Technology > Modeling & Simulation (0.68)
- Information Technology > Data Science (0.46)
Abstract Uncertainties particularly in geological parameters are always present and can be significant if associated with field development. These uncertainties could be perceived by geologists and engineers to exist in the available data. Industry has been using uncertainty analysis to identify, address and mitigate risk. Development strategies and well placement may significantly depend on field geology, maturity of the depletion stage, technological factor, drive resources and other parameters. Well placements optimization most of the time is done based on a deterministic (most likely) case. The optimum placement of wells within geologic uncertainty is the issue addressed in this paper. This paper discusses a new approach and workflow process for applying uncertainty analysis using sector model of an undeveloped reservoir and the optimization of development wells under geological uncertainty. Tornado plots were used to identify the highest critical parameters among the list of uncertainties of the field. Experimental Design was used to select simulation runs to build the proxy model. Monte Carlo analysis was then used to generate the density distribution function of cumulative production to identify the P10, P50 & P90 cases. The probabilistic distribution was used to determine the likelihood of the development case under identified risk parameters. Field operation strategies were considered together with optimization of injector-producer spacing, producer-producer spacing, horizontal completion, well length and orientation with geologic uncertainties. The optimized development plan and well placements were used to generate the cumulative production distribution with uncertainty parameters. This workflow was successfully tested in a large carbonate field.
- Reservoir Description and Dynamics > Reservoir Simulation (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring (1.00)
- (8 more...)
Abstract Albacora Leste, one of the largest Campos Basin deep-water oilfields, was discovered in March of 1986. Oil field development area involves 141km and water depth ranges from 800 to 2000m. In order to exploit the field, 30 horizontal wells - 16 producers and 14 injectors - will be connected to an FPSO unit (P-50). Expected total reserves are 565 million barrels of oil. Albacora Leste main reservoirs are Miocene sandstones with high porosity and permeability. The depositional model is interpreted as a complex turbidity system, mainly represented by channels, lobes and overbank facies. Net thickness ranges from 5 to 35m, suggesting horizontal well drilling. After the deposition stage, erosive channels introduced flow barriers that generated different reservoir compartments. These compartments impacted drainage pattern design and were checked through reservoir pressure data after long term pilot well production, log interpretation, and fluid samples analyses. Small gas caps showing different gas/oil contacts were detected all over the field area, introducing an additional challenge for field development. Intensive application of the following technologies was important to make field development technically and economically successful:high quality 3D seismic; image logs and LWD (logging while drilling); long gravelpacked horizontal wells; thermally insulated flowlines, allowing flow assurance for distant satellite wells; and massive sea water injection for sweep, and reservoir pressure maintenance. In order to avoid scale deposition as a result of sea water injection, a Sulphate Removal Unit was installed in the P-50 FPSO. This paper presents the key aspects of the reservoirs, the drainage modeling and design, as well as the strategy adopted during project implementation, in order to overcome main reservoir uncertainties, such as fluid type, connectivity, and net pay, accomplishing at the end a successful project execution. Introduction The Albacora Leste deep-water giant oil field is located on the northern part of Campos Basin, in southeastern Brazil, about 120km from the São Tomé Cape, Rio de Janeiro State coast, in water depths ranging from 800 to 2,000m (Figure 1). The reservoir depths range from 2,300 to 2,600m, referenced to sea level. Albacora Leste reservoirs are high quality siliciclastic reservoirs from the Tertiary (Miocene sandstones) with average porosities of 30% and average bsolute permeabilities of 3,000mD. Oil gravity ranges from 16.5 to 21.5° API. In order to develop the field, a consortium was formed by PETROBRAS and REPSOL-YPF. PETROBRAS is the operator and holds 90% of working interest, while EPSOL-YPF holds 10%. The field OOIP volume is 3,800 MMBBL. Total recovery for Albacora Leste is estimated to be 565 MMBBL of oil and 10 billion m of gas, with proven reserves of 411 MMBBL of oil and 7.3 billion m of gas.
- Phanerozoic > Cenozoic > Neogene > Miocene (0.45)
- Phanerozoic > Cenozoic > Tertiary (0.34)
- Geology > Sedimentary Geology (1.00)
- Geology > Geological Subdiscipline (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.49)
- Geophysics > Seismic Surveying > Seismic Processing (1.00)
- Geophysics > Seismic Surveying > Seismic Interpretation (1.00)
- Geophysics > Borehole Geophysics (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > South America Government > Brazil Government (0.45)
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Campos Basin > Albacora Field > Albacora Leste Field (0.99)
- South America > Brazil > Campos Basin (0.99)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Reservoir Description and Dynamics > Reservoir Simulation (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- (9 more...)