Protesters blockading oil and gas fields in southern Tunisia have reached an agreement with the government to end a sit-in and allow production to restart immediately, the government and protesters said on 16 June. The City Council of Lafayette, Colorado, on 17 January voted to table an anti-hydraulic-fracturing ordinance that could impede oil and gas development within Lafayette through sanctioning acts of civil disobedience and nonviolent protest.
When the head of Libya’s state energy company visited Sharara oil field in early July, community leaders and workers crowded into a conference room to ask about jobs, training, and services for local people. Public acceptance is a major challenge for the siting of facilities. The offering of compensation to communities potentially helps to create the perception of a fairer distribution of local risks and nonlocal benefits. This may help to prevent or solve siting controversies. Anadarko Petroleum said late on 30 June that it has tested more than 4,000 active oil and gas lines and plugged another 2,400 inactive ones per a state order issued after a fatal home explosion in Firestone, Colorado, in April.
SPE Forum: Enhanced Oil Recovery – The Future is Now! 18 - 23 October 2015 | Cancun, Mexico Managed Pressure Drilling—Niche Technology or the Future of Drilling? Water Management: Is an Ounce of Prevention Worth a Pound of Cure? 22–26 Oct 2012 | Carlsbad, California, USA Excellence in Fracture Stimulation–The Present and Future of Affordable Energy 20–25 May 2012 | Xi'an, China CO2 Geological Storage: Will we be ready in time? Getting to Zero–An incident Free Workplace: How do we get there?
Researchers at Indiana University's School of Public and Environmental Affairs found that public opinion of oil and gas development could be improved if firms were "green certified," meaning that they pledged to adhere to stricter environmental standards than required. In its report "Change the Conversation: Redefining How Companies Engage Investors on Sustainability," nonprofit Ceres provides some guidance on how companies should best engage with their investors on the issue of sustainability. An assortment of sustainability initiatives shows how the oil and gas industry, leveraging its reach, diversity, and resources, is going well beyond just supplying energy to impact the world for the better. In September 2015, the United Nations adopted 17 Sustainable Development Goals, addressing the global challenges facing humanity, including poverty, inequality, health, education, energy, climate, the environment, and prosperity. Are you annoyed by all the wrong things passing for facts about oil and gas?
Africa (Sub-Sahara) ExxonMobil subsidiary Esso Exploration Angola has started oil production at the Kizomba Satellites Phase 2 project offshore Angola. The project involves the development of subsea infrastructure for the Kakocha, Bavuca, and Mondo South fields. Mondo South is the first field to begin production, and the other two satellite fields will follow later this year. The goal is to increase Block 15's production to 350,000 BOPD. Esso (40%) is the operator with BP Exploration Angola (26.67%), Kosmos Energy discovered gas at the Tortue West prospect in Block C-8 offshore Mauritania.
Africa (Sub-Sahara) Equatorial Guinea's Ministry of Mines and Hydrocarbons has notified Ophir Energy that it will not gain an extension for the offshore Block R license. The block contains the deepwater Fortuna gas discovery. Ophir had been seeking to develop the gas using a Golar-converted floating liquefied-natural-gas (LNG) vessel, but failed to secure sufficient financial backing for the project. Front-end engineering design had begun in July 2015. Located approximately 140 km west of Bioko Island, the Fortuna project was to see development of six commercial discoveries in a phased manner. In November 2016, the British oil and gas company created a joint operating company with OneLNG to develop the floating LNG project at the Fortuna gas discovery.
In the exploration and production (E&P) industry attempts at reducing the cost of the well construction by applying various well architecture slim designs has attracted attention from operators for decades. The recent industry downturn has further contributed to a renewed focus on this strategy. In this study we present a slim well design application within the FortunaCo project (a Joint Venture between OneLNG and Ophir), which aims at developing the Fortuna and Viscata fields in Deepwater offshore Equatorial Guinea. An advanced static nonlinear Finite Element engine is used in this process, which considers contact and friction; can handle large deformations and is therefore suitable to carry out buckling analysis. The top hole structural robustness is analyzed using this engine in the event of a worst case axial load, which for this study is assumed to be: The Conductor Pipe (CP) able to take its own weight only, The upper section of the surface casing (inside the CP) free of cement, The full buoyant weight of the Horizontal Christmas tree and Subsea Blowout Preventer applied onto the well.
The Conductor Pipe (CP) able to take its own weight only,
The upper section of the surface casing (inside the CP) free of cement,
The full buoyant weight of the Horizontal Christmas tree and Subsea Blowout Preventer applied onto the well.
This paper demonstrates that the selected numerical model is suitable to estimate critical buckling loads and identify post-buckled modes exerted on surface structural casings. Furthermore, it is shown that the visualization capabilities and speed of the engine allow the operator to optimize the design iteratively in an efficient manner. We conclude that the selected methodology is suitable for the operator to validate a slim well design for a Deepwater development application at concept phase for minimal cost with the necessary level of confidence.
Troudi, Habib (OMV Tunesien Production GmbH) | Chevalier, Francis (OMV Tunesien Production GmbH) | Alouani, Wael (OMV Tunesien Production GmbH) | Mzoughi, Wala (OMV Tunesien Production GmbH) | Abdelkader, Omri (OMV Tunesien Production GmbH)
In Tunisian Ghadames sag basin, a significant portion of natural gas resources are looked within low permeability Ordovician sandstones deposited immediately below the Early Silurian Tannezuft world-class source rock.
The objective of this study was to develop an integrated approach to better estimate the amount of gas stored in this emerging play via the analysis of four fundamental elements: 1) the thermal maturity of the Silurian ‘hot shales’ source rock, 2) the trapping mechanism and the architecture of Upper Ordovician paleo-valleys, 3) the impact of diagenesis-lithofacies association on petrophysical properties, and 4) the fracture distribution/density and their contribution in the production.
The Early Silurian hot shales constitute the essential ingredient for the development of a pervasive gas accumulation play. The gas generated at the deeper part of the basin has charged the underlying Ordovician low-permeability sandstones mainly through complex faults system inherited from the basement. During hydrocarbon maturation and charging, pore pressure increases at rates that exceed the normal gradients, leading to local over-pressure as seen in several wells drilled down to the Ordovician reservoirs. Lateral migration via regional faults is confirmed by numerous discoveries at the edges of the basin far away from the gas kitchen.
Besides the structural closures accumulations, more complex structural/stratigraphic or purely stratigraphic traps are deemed within the Late Ordovician, and documented for instance by the development of incised paleovalleys filled with multiple fluvio-glacial and marine clastic sediments (i.e Algeria, Libya). The discovery of hydrocarbon pay zones outside of structural closures and the result of the long term tests confirm this hypothesis.
Based on seismic data it is generally very hard to recognize the paleorelief marking the base of the Late Ordovician sequence. Key elements from core studies, regional correlations, isochore maps and sequence stratigraphy have been combined accordingly, leading to a conceptual model within the observed framework. It is then possible to identify the multiple incision surfaces associated with reservoirs of Jeffara and M'Krata Formations.
The reservoir quality is considered as a major risk in deep areas (>4 km). Although, the primary pores space have been occluded by quartz overgrowths and clay cementation or lost by lithostatic compaction. The substantial gas rates observed in several wells drilled in the junction of NE-SW and NS fault trends constitute an evidence of the contribution of open fracture into the flow.
This new insight into this play has been used by OMV to identify in Ghadames basin the area with possible "Tunnel Valley features", analogues to those drilled in Libya Murzuk basin (
Abdel-Basset, Mohamed (Schlumberger) | Al-Mufarej, Mishal (Kuwait Oil Company) | Al-Mutawa, Majdi (Kuwait Oil Company) | Chetri, Hom (Kuwait Oil Company) | Anthony, Elred (Kuwait Oil Company) | Al-Zaabi, Hamad (Kuwait Oil Company) | Bolanos, Nelson (Schlumberger) | Ruiz, Hector (Schlumberger) | Harami, Khalid (Schlumberger)
This paper demonstrates the production optimization methodology being used by Kuwait Oil Company to increase production in one of its giant and mature fields by 18% over 5.0 years.
Production optimization is a continuous iterative process to improve production, especially in mature fields. The North Kuwait Redevelopment team has adopted an integrated enhanced and structured process to identify opportunities for production optimization with a pro-active approach focusing on flowing wells and rig-less interventions to tackle production challenges and achieve production targets
Typical mature-field challenges are present. These include water flooding, produced water management, artificial lift, with more than 1000 (vertical, deviated and horizontal) active wells, coupled with high structure complexity and stratigraphic heterogeneity, tight sandstone and carbonate reservoirs, shortage of work-over rigs. These challenges make the field appropriate to apply the production optimization methodology outlined here.
The Heterogeneity Index (HI) process is utilized to rapidly demonstrate production gain opportunities, for a giant mature North Kuwait Sabria field of approximately 1000 wells produce from different reservoirs. The HI process provided a quick screening method of identifying preliminary candidate wells with anomalous behavior (over/under performance) for further analysis and most importantly, provided the foundation for the overall structured production approach. The results from this screening tool were utilized to identify the families of type productivity problems at field and well levels with solution categories for production enhancement. Representative wells were selected for detailed diagnostics based on the relevance and size of productivity impact and the potential of its well deliverability. Once a few "top potential" wells were identified, production engineering workflows were implemented to assess and forecast the potential of production increase and to determine and evaluate the best intervention action.
This production optimization workflow is done in a consistent cycled process considering the ageing condition of the mature field, and the aforementioned challenges.
Approximately 35% of the wells have been selected for further analysis over multiple production optimization cycles spanning approximately 5.0 years. A detailed production engineering workflow provided recommendations of various remedial intervention solutions to improve well production potential via productivity enhancement, water shut-off/conformance, stimulation, additional and/or re-perforations, and Artificial lift optimization. Other advanced technologies were applied to improve various strategies, including completions, perforation, stimulation, and injection/production control. To date (Febrauary, 2018), recommendations for approximately 30% (300) wells have been executed, with a significant oil gain of approximately 18 % of the total field production.
This paper discusses the successful design, testing, and application of a new filter-cake breaker technology based on lactic acid chemistry. This technology provided prolonged delay in filter-cake breakthrough time at 220°F, which ensured coverage of the entire open hole, improved uniform filter-cake removal, minimized brine losses, and exceeded the expected production rates in different layers of the offshore Abu Dhabi reservoir.
Reservoir characterization was a fundamental component in the identification of the proper solution to maximize the return on investment of the assets. Temperature, permeability, porosity, and the nature of the reservoirs were studied thoroughly to determine one solution to be used in different reservoirs. Drilling fluid characterization (non-damaging with proper bridging package) and a proper filter-cake design were crucial to exceed the targeted production of the reservoirs. The paper discusses all steps from the laboratory testing of the breaker, application in different layers of the reservoir, and results obtained from the applications.
Lactic acid precursor was confirmed to be the "one fit solution" to cover the different reservoir layers. Because of its chemical structure, the hydrolysis process is slower than other breaker types currently available, which made it possible to maximize the breakthrough time at elevated temperatures, minimize completion fluid losses, and optimize the completion operations. Equally important, as an acid precursor rather than a live acid, this solution enabled the rig site personnel to implement the solution without affecting the health, safety, and environment (HSE) aspects that are fundamental in offshore locations. The possibility of pumping this solution through the rig pits enabled the jobs to be performed without additional equipment generally required for well stimulation. The achievement of these goals, supported by the higher production observed during the flow-back of the well, demonstrated how this solution maximized the return on investment for the assets located offshore Abu Dhabi.
The innovative use of lactic acid chemistry in the breaker, as compared to the conventional formic acid precursor breakers that are widely available, provided superior delay at higher bottomhole temperatures (in this case, 220°F) because of the slower acid liberation rate.