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Collaborating Authors
South Sudan
Bahrain has announced two natural gas discoveries in the Al-Joubah and Al-Jawf reservoirs, according to state news agency BNA. Nasser bin Hamad Al Khalifa, chairman of the kingdom's energy investment and development arm Nogaholding, has updated Bahrain King Hamad bin Issa Al Khalifa on the discoveries, an official statement said without disclosing estimated reserves. Bahrain's energy strategy is likely to be decided in the next 6 months, Nogaholding's chief executive told Reuters. The Gulf Arab state's 2018 discovery of the Khaleej al-Bahrain field was its largest oil and gas find since 1932 and is estimated to contain at least 80 billion bbl of shale oil. The two unconventional gas reservoirs, Al-Juba and Al-Jawf, are located under the existing onshore gas-producing fields of Al-Khuf and Al-Onaiza.
Oilfield Places:
SPE Disciplines:
Country:
- North America > United States > Oklahoma > Oklahoma County > Oklahoma City (0.19)
- North America > Canada > Alberta > Census Division No. 6 > Calgary Metropolitan Region > Calgary (0.19)
- Asia > Russia > Ural Federal District > Tyumen Oblast > Tyumen (0.19)
- (8 more...)
Oilfield Places:
- North America > United States > Texas > Permian Basin > Yeso Formation (0.99)
- North America > United States > Texas > Permian Basin > Yates Formation (0.99)
- North America > United States > Texas > Permian Basin > Wolfcamp Formation (0.99)
- (21 more...)
The Research on Decommissioning and Abandonment Engineering Practice of Onshore Oilfield: A Case Study of Block 1/2/4 in South Sudan
Liu, Qi (CNPC Engineering Technology R&D Company Limited) | Liu, Huifeng (CNPC Engineering Technology R&D Company Limited) | Wang, Xi (CNPC Engineering Technology R&D Company Limited) | Li, WanJun (CNPC Engineering Technology R&D Company Limited) | Yang, Guobin (CNPC Engineering Technology R&D Company Limited) | Bahedaer, Baletabieke (CNPC Engineering Technology R&D Company Limited) | Yan, Long (China National Oil and Gas Exploration and Development Company Ltd.) | Yan, Jun (China National Oil and Gas Exploration and Development Company Ltd.) | Yang, Yifeng (China National Oil and Gas Exploration and Development Company Ltd.) | Tian, Huiying (China National Oil and Gas Exploration and Development Company Ltd.) | Lu, Peng (China National Oil and Gas Exploration and Development Company Ltd.)
Abstract At the end of the lifespan of this onshore oilfield development, all wells and oil production system, transmission pipelines and all surface infrastructures shall be decommissioned in accordance with international guidelines for abandonment of oil and gas facilities. The development and production period relevant to Block 1/2/4 shall be ceased in 2033 as the PSC law approved by South Sudan Government. Considering that South Sudan is located along the Nile River in Africa, necessary measures shall be taken with respect to activities in the field to ensure effective protection for the environment. In addition, difficulties which have negative impact on decommission assessment shall be taken into account, such as inadequate wells data, the destruction of the facility by war, high security risks of Block 1/2/4, costly decommissioning and abandonment fees and so on. This paper combines the practice of Block 1/2/4 in South Sudan to introduce the decommissioning plan, abandonment working process, standard operation procedure for wells and surface facility disposal, and the calculation of the decommissioning fund. The decommissioning may include complete removal or abandonment in-situ which based on an evaluation of cost, safety and environmental impact. While a detailed decommissioning and abandonment proposal has been compiled and updated during the production phase of the project. When the final decommissioning and abandonment plans have been developed for upstream and midstream, the costs have been updated accordingly. These estimates had utilized by the operators to fund the decommissioning and abandonment obligations in accordance with the provisions of the oil company. The D&A task was successful and finally approved by the authority of government. Due to the successful completion of the decommissioning task of Block1/2/4, a completed decommissioning and abandonment management system has been established, including D&A cost calculation and standard operation procedure for wells and facility disposal, which can lower the environmental risk and reduce the capital expenditure at the end of the project. It can be regarded as a classic practice in petroleum industry and .
abandonment, abandonment engineering practice, balance cement plug, block 1 2 4, casing and cementing, casing design, cellar, cement plug, decommissioning, detailed operating procedure, Engineer, execution plan, exploratory well, knowledge management, obtain necessary technical information, plug, requirement, South Sudan, spot balance cement plug, Upstream Oil & Gas
Evaluation of Continuous Surfactant Flooding in North East Africa: Case Study of Bentiu Reservoir
Elhag, Hani Hago (Asia Pacific University, Malaysia) | Abbas, Azza Hashim (Asia Pacific University, Malaysia) | Gbadamosi, Afeez (Afe Babalola University, Nigeria) | Agi, Augustine (Universiti Teknologi Malaysia, Malaysia) | Oseh, Jeffrey (Afe Babalola University, Nigeria) | Gbonhinbor, Jeffrey (Niger Delta University, Nigeria)
Abstract Recently, continuous surfactant flooding (CSF) has been devised as an improvement to overcome the limitation of conventional surfactant flooding (SF). The utilization of CSF depends on several factors such as surfactant type and reservoir characteristics. This study performs the feasibility study of utilizing CSF for a marginal field of Bentiu reservoir in Sudan with a production history of 20 years. The reservoir is moderately heterogeneous reservoir. Thirty-six (36) cores from the natural reservoir extension of its most effective basin were evaluated. The evaluation focused on the role of core properties such as porosity and permeability on CSF. The comparison of the results was benchmarked by water flooding and the conventional surfactant flooding. Numerical simulation CMG STARS was used to perform the sensitivity analysis on the core scale. The results of the study showed 5 main ranges of the cores available after grouping. The highest recovery factor of water flooding was in the range of 48 (+/- 1.3%). There were no significant changes in the cumulative oil produced; however, the core physical properties affected the duration needed to reach the production plateau. For CSF, the highest recovery was in the fourth group of cores. In term of water cut, the percentages declined slightly with a range of 0.01 to 0.09 % with lowest percentage value water cut recorded at 99.90% and the highest result of 99.99%. Moreover, the recovery factor reached up to 45.80% using water flooding method and increased up to 90.41 % in CSF method. The remaining oil saturation reached to 0.35 during water flooding and dropped to 0.061 during the CSF. Moreover, the result obtained in CSF which indicates that the optimum porosity and permeability range of 0.26 to 0.29 in porosity and 390 to 2220 mD in permeability is the suitable range to be implemented in continuous surfactant application. Hence, based on the obtained results, CSF shows promising effects for use in marginal oil fields.
application, bentiu reservoir, chemical flooding methods, continuous surfactant flooding, CSF, enhanced oil recovery, enhanced recovery, evaluation, flow in porous media, Fluid Dynamics, gbadamosi, oil production, Oil Recovery, oil saturation, oilfield, permeability, reservoir, surfactant, Surfactant Flooding, Upstream Oil & Gas, water cut, waterflooding
Oilfield Places:
- Africa > Sudan > Muglad Basin (0.99)
- Africa > South Sudan > Muglad Basin (0.99)
SPE Disciplines:
Deeper Re-completions Exploited Bypassed Oil in Massive Heavy Oil Reservoir: Case Study
Tang, Xueqing (1Petro Energy Co., Khartoum, Sudan) | Dou, Lirong (1Petro Energy Co., Khartoum, Sudan) | Wang, Ruifeng (2RIPED, PetroChina, Beijing, China) | Gabir, Alsadig Mohmoud (1Petro Energy Co., Khartoum, Sudan) | Musa, Mouiz Hamza (1Petro Energy Co., Khartoum, Sudan)
ABSTRACT Fula field at Block 6, Sudan contains crude of 16.8 to 19 °API with in-situ viscosity of 497 cp in Bentiu formation. It was on production in March, 2004 and has produced 14% of original oil in place. Massive and unconsolidated sandstones inter-bedded with thin (3 to 13 ft) and discontinuous shales possess high horizontal and vertical permeabilities (2 to 9.53 Darcies). Lateral dimensions of shale bodies range from 1,000 to 2,000 ft. To extend oil production life with water-free, initial development strategy was to perforate the upper and more permeable zones (Perforations are 30% of entire zones) to obtain profitable productivity. After fieldwide water breakthrough, based on the studies of bypassed oil distribution, the following innovative deeper re-completions have been applied in high-water-cut wells (water cut more than 80%) to exploit the bypassed oil zones and new pay zones that have been missed below the existing productive zones. squeeze cement into the existing high-water-cut zones, located at the upper portion of entire pay zones. Those long wormholes communicating with aquifer caused by deep sanding should be cemented. perforate partially the lower portion of pay zones with optimal shot density. 30 to 40% of entire pay zones and shot density of 5 shots per foot are recommended. Perforation tunnel optimization can be run for concrete well conditions. Progressing Cavity Pumps operate at low frequencies less than 30 Hz to regulate proper pressure drawdown less than observed critical value of sanding from field tests and water coning. Field production data indicate that this workover campaign has achieved more than 2-fold oil gain and reducing water cut by 30 to 50% compared to previous water cuts of over 80%, also, water cut plus dynamic fluid level remain relatively stable over 6 months.
SPE-AFRC-2582438-MS
bentiu reservoir, BOPD, Completion Installation and Operations, conformance improvement, deeper re-completion exploited bypassed oil, enhanced recovery, massive heavy oil reservoir, net pay thickness, oil rate, pay zone, presentation, pressure drawdown, producer, reservoir, sand unit, Upstream Oil & Gas, water cut, wormhole
Country:
- Asia > China (0.95)
- Africa > South Sudan > Northern Liech > Bentiu (0.29)
- Africa > Sudan > Western Korfofan (0.26)
- Africa > Sudan > Southern Darfur (0.26)
Oilfield Places:
- Asia > China > Shandong > North China Basin > Shengli Field (0.99)
- Asia > China > Henan > Nanyang Basin > Biquan 10 Block > Henan Field > Hetaoyuan Formation (0.99)
- Africa > Sudan > Western Korfofan > Muglad Basin > Fula Basin > Block 6 > Fula Field (0.99)
- (2 more...)
Petroleum Exploration Potential on Abu Gabra Formations in Fula Sub-basin, Muglad Basin, Sudan
Weili, Ke (1Research Institution of Petroleum Exploration and Development, PetroChina, Beijing, China) | Guangya, Zhang (1Research Institution of Petroleum Exploration and Development, PetroChina, Beijing, China) | Aixiang, Liu (1Research Institution of Petroleum Exploration and Development, PetroChina, Beijing, China) | Yonglin, Zheng (2Petro-Energy Co., Ltd., Khartoum, Sudan) | Yongjun, Yu (2Petro-Energy Co., Ltd., Khartoum, Sudan)
ABSTRACT Fula sub-basin is one of chasmic structure units with rich petroleum accumulation within Muglad basin. In the past, thick sandstones of Bentiu was considered as main petroleum accumulation targets sealed by faults and anticlines, and most petroleum generated by AG source kitchen has migrated to upper formations along big faults, and furthermore, sandstones inside AG formation of are thin with poor permeability and porosity caused by compaction. Recently, some works have been done specially on AG formation, including small fault interpretation, seismic sedimentary analysis and thin layer inversion, resulting in new petroleum discoveries within middle AG formation, which reveals that AG formation has also good petroleum accumulation abilities. Comprehensive study shows that there developed many small faults within AG period, which could seal sandstones of AG formation laterally, forming effective faulted block within AG formation. Sandstones of delta and sub-water channel could be found. Within AG4 and AG2 formations, there are mainly lacustrine facies. Channel sandstones occurred regression and the area of alluvium fan decreased AG shale has high matter abundance, high hydrocarbon generating potential and kerogen type I, II with middle to high mature, showing good hydrocarbon generation ability. Although sandstones of AG formation have relatively low permeability and porosity, these sandstone have good logging response on hydrocarbon could be sealed by local surrounding mudstones and. All above reveals that AG combination is near-source reservoir combination. Low-amplitude anticline and structure-lithology reservoir models are favorite reservoir models in Fula sub-basin. In the west slope, especially the lower places of the slope are the areas of huge sedimentary accumulation should be favorite prospects. As for the east slope, low-amplitude anticline bounded by small faults that developed during AG period should be the favorite area for exploration, which has been proved by successful drilling activities. In Fula sub-basin, AG structure-lithology complex reservoir combination should be the favorite type for drilling as per under these two key factors, the petroleum could be well accumulated. Currently, there have two important petroleum discoveries of channel sandstone and delta sheet sandstone in AG formation, proving that AG formation still has good potential for drilling.
SPE-AFRC-2565579-MS
Abu Gabra formation, AG formation, delta facies, facies, fula sub-basin, lacustrine facies, mudstone, Muglad Basin, petroleum discovery, petroleum exploration potential, Reservoir Characterization, reservoir combination, sandstone, sequence, source rock, structural geology, Upstream Oil & Gas, value range
Country:
- Africa > Sudan (1.00)
- Africa > South Sudan > Northern Liech > Bentiu (0.27)
Oilfield Places:
- Africa > Sudan > Muglad Basin (0.99)
- Africa > South Sudan > Unity > Muglad Basin > Fula Basin > Bentiu Formation (0.99)
- Africa > South Sudan > Unity > Muglad Basin > Fula Basin > Aradeiba Formation (0.99)
- (2 more...)
SPE Disciplines: Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
ABSTRACT Beyond offshore West Africa where modern densely-sampled data from ships and satellites have played a key role in current understanding of passive margin evolution, Africa is in general rather unevenly known, especially in the subsurface in more remote areas. The GIS-based Exploration Fabric of Africa (EFA, the ‘Purdy project’) was designed to address that problem. It includes structural features such as faults and basin outlines but at a very high and often generalized level, divorced from their underlying genetic linkages. We have undertaken to compile a more detailed tectonic synthesis aimed to integrate understanding of the oceanic margins with the continental realm. This is an overlay to EFA with a variety of public domain, published, non-exclusive, and derivatives of proprietary work at a closer and more detailed level, importantly guided by known patterns of structural styles. Potential field (gravity and magnetic) data provide guidance in locating, extending, and connecting key mapped features; we then rely on the kinematic patterns to predict missing details in a testable interpretation. The result is a detailed structural features map that can function as a framework within which to target and prioritize both conventional and unconventional activity by operators and licensing/regulatory organizations. We illustrate the process in theory and in practice along the Central African Rift System (CARS), where data is sparse. This fault linkage systems approach has flagged underexplored areas where unmapped structure is likely that could, for example, be targeted with hi-resolution geophysical data. A similar system to CARS appears to cross southern Africa from Namibia to Tanzania – a “Southern Trans-African Rift system" or STARS. Exploration in the eastern Owambo Basin resulted in the mapping of a pull-apart basin from depth-to-basement inversion of high-resolution magnetic data and subsequently studied with structural modeling. Thinking in terms of such fault and structural systems, this ‘Kavango Basin’ can be related along strike to the Karoo Basins in Eastern Africa via features such as the Omaruru lineament, implying the possibility of a fairway of extensional basins and shears across the continent that are not obvious in existing low-resolution data. STARS represents a blue-sky frontier concept for both conventional and nonconventional exploration potentially offering new exploration leads, the ultimate objective of big picture work.
SPE-AFRC-2571578-MS
Country:
- Asia > Middle East > Yemen (1.00)
- Africa > Sudan (1.00)
- Africa > Namibia (1.00)
- (6 more...)
Geophysics:
- Geophysics > Seismic Surveying (0.94)
- Geophysics > Magnetic Surveying (0.89)
Oilfield Places:
- South America > Brazil > Rio Grande do Norte > South Atlantic Ocean > Potiguar Basin (0.99)
- Africa > Sudan > Muglad Basin (0.99)
- Africa > South Sudan > Muglad Basin (0.99)
- (20 more...)
SPE Disciplines:
A Success Story for a High-Temperature Foam-Assisted Lift Application in a Mature Field, Gulf of Thailand
Sompopsart, Suwin (PTT Exploration and Production Limited) | Toempromraj, Wararit (PTT Exploration and Production Limited) | Nadoon, Apiwat (PTT Exploration and Production Limited) | Charoencheep, Phongsiri (PTT Exploration and Production Limited) | Sukchum, Techasit (PTT Exploration and Production Limited) | Harnboonzong, Pithak (PTT Exploration and Production Limited) | Whangkitjamorn, Jugkapun (PTT Exploration and Production Limited) | Lerlertpakdee, Pongsathorn (PTT Exploration and Production Limited) | Thanasutives, Patana (PTT Exploration and Production Limited) | Tivayanonda, Vartit (PTT Exploration and Production Limited) | Charoenniwesnukul, Kritsada (PTT Exploration and Production Limited) | Thongpian, Duangkwan (PTT Exploration and Production Limited) | Kultaveewuti, Chatsuda (PTT Exploration and Production Limited) | Wongrattananon, Chuayrach (PTT Exploration and Production Limited) | Ketpreechasawat, Suampa (PTT Exploration and Production Limited) | Wongpattananukul, Kongphop (PTT Exploration and Production Limited) | Pulputtapong, Jirayu (PTT Exploration and Production Limited) | Sirimongkolrat, Saran (PTT Exploration and Production Limited) | Pongsripian, Winit (PTT Exploration and Production Limited) | Phanich-aphichai, Krittapas (PTT Exploration and Production Limited) | Wattanasuwankorn, Reawat (Halliburton) | Thompson, Stewart (Halliburton)
Abstract Liquid loading is a common problem in many gas wells in the Gulf of Thailand. At the late stage of well life, reservoir pressure declines, gas production rates decrease, and liquid begins collecting on the wall of the tubing and accumulates at the bottom of the well, eventually killing the well. This paper presents promising results from foam-assisted lift (FAL) field trials to remove liquids, re-establish flow, and increase production in previously idle wells. The injection of foaming agents can be used to remove liquids through artificial lift. High downhole temperatures in Gulf of Thailand wells requires special foaming agents that can operate at 450°F. Using high-temperature foaming agents in nearly dead wells can extend their life by reducing the production decline rate and preventing premature water loadup. Because foam density is significantly lower than liquid density, hydrostatic pressure is reduced, which assists the flow of fluids from the bottom hole to the surface, resulting in increased gas production rates and reserve recovery rates compared to natural flow. An operator in the Gulf of Thailand experienced promising results from a field trial using high-temperature FAL with batch treatments in five high-temperature wells in the offshore field. Three wells that were previously not flowing were able to flow to the production system after treatment. One well was able to flow at even higher rates after the FAL treatment compared to prejob rates. Only one well did not respond to the treatment. Understanding the FAL procedure and addressing critical issues before implementing the technology can help enhance mature field production in otherwise idle wells. Using FAL in mature wells with low or no production can help remove liquid accumulation at the bottom of the well, preventing premature water loadup and returning idle wells to production.
agent, artificial lift system, downhole intervention, FAL, foamer product, gas flow, gas injection, gas lift, gas production, gas Well Deliquification, Gulf, high-temperature foam-assisted lift application, hydrostatic pressure, international petroleum technology conference, intervención de pozos petroleros, mature field, operator, production control, production enhancement, production monitoring, recompletion, Reservoir Surveillance, Thailand, Upstream Oil & Gas, Well Intervention, well production, wellbore
Country:
- Asia > Thailand (1.00)
- Africa > South Sudan > Upper Nile (0.24)
SPE Disciplines:
- Production and Well Operations > Well Intervention (1.00)
- Production and Well Operations > Well & Reservoir Surveillance and Monitoring (1.00)
- Production and Well Operations > Artificial Lift Systems > Gas lift (0.70)
- Production and Well Operations > Artificial Lift Systems > Gas well deliquification (0.49)
Summary The southern Sudan rift basins form part of the Mesozoic Central African Rift System (CARS) and span an area 1000 km wide and 800 km along strike. They consist of two major NW-SE trending rift basins; the Muglad and the Melut. Following a series of gravity, magnetic and seismic related studies (Fairhead et al., 2012) most of the rift system’s kinematics and structural evolution are reasonably well understood.. However, ambiguities exist, where these rift basins coalesce towards the Kenyan border and the structural continuation and linkage to the Anza Rift (figure 1). This partly relates to a data gap across political borders. This study (King, 2012) utilised the 5’ (~10km) and 1km grids of gravity and magnetic data from Getech’s African Gravity Project (AGP) and African Magnetic Mapping Project (AMMP). The ground gravity station distribution is shown as red dots and the aeromagnetic surveys are shown by the blue polygons in Figure 2. The regional rift basin setting is given by Figure 1 and shows the uncertain relation between the South Sudan rift basins and the Anza rift basin in Kenya. These data sets were interpreted using a range of techniques to provide an integrated robust regional interpretation that reveals insights into the rift evolution of South Sudan and northern Kenya. The principal findings are evidence for an E-W trending shear zone linking the South Sudan basins to the Anza Rift, and the identification of a discrete N-S oriented basin related to a small shear zone in South Sudan.
Geophysics:
- Geophysics > Magnetic Surveying (1.00)
- Geophysics > Gravity Surveying (1.00)
Oilfield Places:
- Africa > Kenya > Anza Basin (0.99)
- Africa > Sudan > Muglad Basin (0.98)
- Africa > South Sudan > Muglad Basin (0.98)
- (2 more...)
Abstract This paper illustrates an innovative field-scale application of injecting condensate gas and recycling gas in Jake field, Sudan. This field has two production series, namely AG condensate gas pools and Bentiu oil pool from bottom to up, with the former 3520 ft. below the Bentiu reservoir and 1695 psi of initial reservoir pressure difference. Bentiu pool of Jake field is a medium crude oil (29 API) pool with strong aquifer support. Well productivity was 500 BOPD. Operator intended to inject high-pressure condensate gas into Bentiu pool to increase field output, whereas was confronted with following challenges: 1) injection of condensate gas in an easy-to-operate wellbore configuration; 2) optimization of injection parameters to achieve highest output; 3) suppress aquifer water breakthrough. Field scale application had been optimized and implemented since 2010:1) High-pressure condensate gas had been injected into two updip crest Bentiu wells in the same well bore, following a huff-and-puff process, well output amounted 4,000 to 13,800 BOPD under natural flow; 2) 1/4 recycling gas volume from compressors was re-injected into 12 downdip wells at controllable pressure to avoid early water breakthrough; 3) The remaining recycling gas was utilized to gas-lift other five updip wells. Oil producers were reduced from 19 to 7 comparing to original field development plan, while oil rate ascended from 22,000 to 30,000 BOPD, with watercut dropping to 7% from 15%, achieving a high offtake rate of 6%. Reservoir simulation indicated ultimate recovery factor is expected to be over 50% with such full-field gas injection. Conclusions drawn from field scale injection of condensate gas and recycling gas were as follows:1) condensate gas injection in the same well bore was technically innovative and operationally robust; 2) recycled gas injection into downdip wells helped detain water breakthrough; 3) field scale application had evidenced outstanding success with high output and high offtake rate.
application, artificial lift system, bentiu pool, BOPD, complex reservoir, condensate reservoir, downdip well, enhanced recovery, gas injection method, gas lift, gas zone, GOR, injecting condensate gas, Jake field, Modeling & Simulation, oil zone, perforation, psia, puff process, recycling gas, scf stb, Upstream Oil & Gas, water cut
Country:
- Africa > South Sudan > Northern Liech > Bentiu (1.00)
- North America > United States > Gulf of Mexico (0.60)
Oilfield Places:
- Oceania > Australia > Northern Territory > Amadeus Basin > Permit OL5 > Mereenie Field > Stairway Formation (0.99)
- Oceania > Australia > Northern Territory > Amadeus Basin > Permit OL5 > Mereenie Field > Pacoota Formation (0.99)
- Oceania > Australia > Northern Territory > Amadeus Basin > Permit OL5 > Mereenie Field > Horn Valley Formation (0.99)
- (7 more...)
SPE Disciplines:
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