The Experts below are selected from a list of 30 Experts worldwide ranked by ideXlab platform

Tarantino Alessandro - One of the best experts on this subject based on the ideXlab platform.

  • Proof-of-concept for a probe to measure pore water pressure in oil-water saturated porous rock
    'Elsevier BV', 2021
    Co-Authors: Capotosto Anastasia, De Carvalho Faria Lima Lopes Bruna, Tarantino Alessandro
    Abstract:

    The identification of the Oil/Water Contact (OWC) in a hydrocarbon reservoir is crucial for the determination of its volume and it is also important for detailed petrophysical calculations. Estimation of the OWC requires the determination of the Free Water Level (FWL). Routine practice in the oil and gas industry involves drilling multiple Discovery Wells since the undulation of the rock layers confining the hydrocarbon reservoir does not generally enable a single Discovery well to intercept the water phase. Well drilling is expensive and industry looks forward to approaches to reduce the number of Wells required for estimation of the OWC. In this context, this paper presents the proof-of-concept for a probe to measure pore water pressure in oil-water saturated porous rock. This would allow predicting the depth of the FWL in hydrocarbon reservoirs even if the single Discovery well does not go through the OWC. This probe could significantly improve the appraisal process and guide the drilling campaigns, saving time, money and reducing the environmental impact of hydrocarbon search. The probe prototype was validated at laboratory scale via measurements of water pressure in core plugs saturated with water and oil. Mock-up tests on sandstone core plugs have shown that the probe can successfully measure water pressure in samples saturated with water and oil as long as the water phase is continuous in the pore space. The paper has therefore provided a proof-of-concept for a technology that can now be moved to the next readiness level

F. Al Ameri - One of the best experts on this subject based on the ideXlab platform.

  • First Time Offshore Abu Dhabi-Successful Appraisal Drill Stem Testing Operations in Extreme Sour Environment - A Case Study
    Day 3 Wed November 09 2016, 2016
    Co-Authors: N.. Iabbassen, A.m.. M. Al-marzouqi, H.s.. S. Slatewala, Jesus A. Jimenez, H. Abdul Karim, K.. Sax, A. Al Shateri, R.. Sutherland, D.. Barrow, F. Al Ameri
    Abstract:

    Abstract As part of of the studies being done aiming to secure bigger gas and oil resources in the UAE, several fields have been undergoing extensive appraisal & evaluation efforts over the past few years. Starting from a review of seismic, petrophysical and well test data from Discovery Wells, new appraisal Wells have been drilled, logged and tested to refine reservoir models and evaluate static and dynamic reservoir properties. With a focus on determining economic viability, productivity and reserves, well testing is a key source of information, yielding fluid samples, productivity, formation mobility and prodiving key indications about optimal completion options such as well inclination or completion method. To demonstrate the existence of moveable petroleum in a reservoir and/or to provide an indication of the potential productivity of that reservoir, well testing is of particular importance to obtain critical information about undeveloped reservoirs. Well testing provides a full understanding of the attributes of a well so that it can be operated profitably and efficiently. A recently drilled appraisal well includes deep oil / gas reservoirs containing up to 38% of hydrogen Sulfide (H2S) and 7% of carbon dioxide (CO2) was successfully tested using Drill Stem Test (DST) in Abu Dhabi offshore field. In order to successfully appraise this field with its specific nature of reservoir fluids that makes all drilling and data gathering operations extremely challenging, many problems had to be solved in well testing techniques. It had to focus on optimal fluids containment and minimization of release. To achieve those aims, several modifications of the equipment were required. It required extensive risk assement sessions with all service providers and rig contractor, in addition to the real time monitoring of all surface and downhole parametres. A systematic multi discipline planning approach with attention to detail, rigorous planning and team work, were some of the key success factors in delivering the objectives in a safe and efficient manner.

J. W. Flannery - One of the best experts on this subject based on the ideXlab platform.

  • Kizomba, a Deep-Water Giant Field, Block 15 Angola
    2003
    Co-Authors: S. Anne Reeckmann, D. K. S. Wilkin, J. W. Flannery
    Abstract:

    During the middle to late 1980s, Exxon Exploration Company embarked on a series of global integrated regional geologic studies, culminating in the Discovery of several giant oil and gas fields. Aggressive acreage-capture strategies were initiated based on these studies, with early participation in opening tender rounds in the identified high-potential basins. From a position of having no acreage in the Congo Basin, offshore Angola, ExxonMobil rapidly became the largest deep-water acreage holder in Angola. Block 15 was included in the first tranches of deep-water acreage offered by the Angolan government and was awarded to a contractor group led by ExxonMobil's subsidiary, Esso Exploration Angola (Block 15) as operator. After early two-dimensional seismic acquisition to high-grade areas of interest, 4000 km2 of high-quality, three-dimensional seismic data was acquired for prospect mapping. Wildcat drilling during 1997–2002 resulted in 13 discoveries in water depths ranging from 500 to 1400 m. Recoverable hydrocarbons are estimated to be in excess of 3.5 billion BOE, with significant undiscovered potential remaining on the block. Oil gravities range from 24 to 35 API. Four of the discoveries (Hungo, Chocalho, Kissanje, and Dikanza) make up the giant Kizomba field complex, with recoverable hydrocarbons of more than 2.0 billion bbl. Each of the Discovery Wells penetrated multiple high-quality, deep-water channel sandstones with oil-water contacts controlled by a combination of structural spill, fault leak, and top seal failure because of buoyancy effects of hydrocarbon columns approaching 1000 m. Reservoirs range from 500 to 1900 m below mud line. The hydrocarbons occur in combination structural-stratigraphic traps. The large north-trending structures are a result of Oligocene–Miocene extension with associated movement of Aptian salt, culminating in middle Miocene to recent diapirism. Lateral seal is provided by stratigraphic pinch-out and onlap of reservoir facies at the margins of the large west-trending channel complexes. Top seal is formed by overlying channel abandonment facies or by prograding slope shales. Reservoirs are early to middle Miocene in age and are dominantly turbidites with associated debris flows deposited in channel complexes on the middle to lower slope. Reservoir properties are excellent. Kizomba will be ExxonMobil's first operated Angolan oil development, with production start-up expected during 2004. The development will take place in approximately 1200 m of water. The first phase, Kizomba A, will involve about half of the Kizomba reserves (approximately 1 billion BOE). The primary drive mechanism for these relatively shallow reservoirs will be waterflood with injection of associated gas early in project life. Production will be via dry trees from a tension-leg platform with associated subsea facilities for injection Wells. Oil will be produced to a floating production storage and offloading (FPSO) vessel, which will offload to tankers via a nearby catenary anchor-leg mooring buoy. The second phase, Kizomba B, will be developed by a similar combination of subsea and surface wellhead platform facilities tied to a second FPSO. The successful Discovery of this giant field is a result of the application of leading-edge technologies systematically integrated into regional exploration experiences and strategies. The future will involve continued emphasis on innovative development technologies to maximize production in this challenging deep offshore environment.

Xinhua Ma - One of the best experts on this subject based on the ideXlab platform.

  • Application of Discovery process models in estimating petroleum resources at the play level in China
    Nonrenewable Resources, 1997
    Co-Authors: Zhuoheng Chen, Richard Sinding-larsen, Xinhua Ma
    Abstract:

    Discovery process modeling has gained wide acceptance in the Chinese exploration community. In recent years, a variety of Discovery process models have been applied to the prediction of undiscovered petroleum resources at the play level in sedimentary basins in China. However, challenging problems have been encountered, particularly when one method alone has been applied to small plays in nonmarine sedimentary basins or in plays with an unusual order of Discovery Wells. This paper presents results gotten by using the lognormal Discovery process model of the Geological Survey of Canada and the geoanchored method for three petroleum plays in basins with different geologic settings. Although the predicted shapes of the parentsize distributions which use these two models, were not always similar, the expected values of the total resources and the number of fields (pools) to be discovered are comparable. The combined use of two Discovery process models in the same play compensates for the weaknesses in one method compared with the other and vice versa. Thus, more reliable estimates are the result.

Capotosto Anastasia - One of the best experts on this subject based on the ideXlab platform.

  • Proof-of-concept for a probe to measure pore water pressure in oil-water saturated porous rock
    'Elsevier BV', 2021
    Co-Authors: Capotosto Anastasia, De Carvalho Faria Lima Lopes Bruna, Tarantino Alessandro
    Abstract:

    The identification of the Oil/Water Contact (OWC) in a hydrocarbon reservoir is crucial for the determination of its volume and it is also important for detailed petrophysical calculations. Estimation of the OWC requires the determination of the Free Water Level (FWL). Routine practice in the oil and gas industry involves drilling multiple Discovery Wells since the undulation of the rock layers confining the hydrocarbon reservoir does not generally enable a single Discovery well to intercept the water phase. Well drilling is expensive and industry looks forward to approaches to reduce the number of Wells required for estimation of the OWC. In this context, this paper presents the proof-of-concept for a probe to measure pore water pressure in oil-water saturated porous rock. This would allow predicting the depth of the FWL in hydrocarbon reservoirs even if the single Discovery well does not go through the OWC. This probe could significantly improve the appraisal process and guide the drilling campaigns, saving time, money and reducing the environmental impact of hydrocarbon search. The probe prototype was validated at laboratory scale via measurements of water pressure in core plugs saturated with water and oil. Mock-up tests on sandstone core plugs have shown that the probe can successfully measure water pressure in samples saturated with water and oil as long as the water phase is continuous in the pore space. The paper has therefore provided a proof-of-concept for a technology that can now be moved to the next readiness level