DeAnn Craig, the first woman to hold the position of SPE President and who also held the top role at... Steve Holditch, who served as SPE President in 2002 and was a fixture of the Texas A&M Universit... Whiting Petroleum appointed Correne S. Loeffler as chief financial officer. He has more than 20 years of experience in the gl... ROVOP, a subsea robotics company, promoted David Lamont as CEO. He was previously the chairman of th... Jud Bailey was appointed vice president of investor relations at BHGE, effective August. Occidental Petroleum elected Robert “Bob” M. Shearer to its board of directors. Margaret K. Dorman was appointed to the board of directors at Range Resources, which was mutually ag... Extraction Oil & Gas announced that former US Commerce Secretary Donald L. Evans has resigned fr... Halcón Resources appointed Richard Little as CEO.
By International Petroleum Technology Conference (IPTC) Monday, 25 March 0900-1600 hours Instructors: Olivier Dubrule and Lukas Mosser, Imperial College London Deep Learning (DL) is already bringing game-changing applications to the petroleum industry, and this is certainly the beginning of an enduring trend. Many petroleum engineers and geoscientists are interested to know more about DL but are not sure where to start. This one-day course aims to provide this introduction. The first half of the course presents the formalism of Logistic Regression, Neural Networks and Convolutional Neural Networks and some of their applications. Much of the standard terminology used in DL applications is also presented. In the afternoon, the online environment associated with DL is discussed, from Python libraries to software repositories, including useful websites and big datasets. The last part of the course is spent discussing the most promising subsurface applications of DL.
LLOG Exploration Company awarded McDermott International a contract valued at $1 million to $50 million for deepwater subsea pipeline tiebacks and structures from the Stonefly development to the Ram Powell platform, located approximately 140 miles southeast of New Orleans. The scope of work includes project management, installation engineering, subsea structure and spoolbase stalk fabrication, and subsea installation of the subsea infrastructure to support a two-well subsea tieback from the Stonefly development site to the Ram Powell platform via a 60,000-ft, 6-in.-diameter McDermott will also design, fabricate, and install a steel catenary riser, a pipeline end manifold, and two in-line sleds. The Stonefly development includes the Viosca Knoll 999 area where the contractor is scheduled to use its 50-acre spoolbase in Gulfport, Mississippi, for fabrication and reeled solutions. The subsea tiebacks and structures are scheduled to be installed using McDermott’s North Ocean 105 vessel in Q3 2019.
Ocean bottom node (OBN) SRME that combines OBN and streamer data is known to be an effective way to predict surface-related multiples in OBN data. However, the available streamer data often have limited offset/azimuth coverage. Additionally, the double source wavelets due to the convolution of OBN and streamer data limit the bandwidth (loss of low and high frequency) of the predicted multiples. OBN model-based water-layer demultiple (MWD) overcomes such limitations and is a good complement of OBN SRME; MWD replaces the streamer data with the water-bottom Green’s function that has no offset/azimuth limitation and keeps the full bandwidth of the input data. With Gulf of Mexico (GOM) OBN data over the Atlantis field, we illustrate the benefit of joint SRME and MWD over SRME alone with the improved attenuation of low-frequency multiples and water layer-related multiples.
Presentation Date: Monday, October 17, 2016
Start Time: 3:45:00 PM
Presentation Type: ORAL
This paper studies on the vortex-induced vibration of a cylinder in combination of uniform and oscillating flows. The dynamic mesh technique are used to simulate the circular cylinder motion. An elastically supported cylinder placed in uniform flow and also in combination of uniform and oscillating flows are simulated. The uniform and oscillating flows are both in the x direction. SIMPLE algorithm is used to solve the Navier-Stokes equations. In the paper, we compute the lift and oscillating motion amplitude as functions of Reynolds number and time at different mass ratios. Simulations show the vortex-induced vibration process of an elastically supported circular cylinder in uniform flow. We compare the oscillating motion amplitude of cylinder and lift coefficient in combined flows at different mass and damping ratios. The lock-in region of the cylinder vibration system with low mass ratio is wider than that of high mass ratio. The amplitude of oscillating cylinder decreases when damping ratio increases.
Marine risers remain to be technically challenging in deep sea. More and more pivotal components of the circular cylinder shape represented by marine risers are widely used in offshore platforms designs and subsea pipeline systems. Many works focus on the research of a circular cylinder in uniform flow and oscillating flow. Many excellent experiments and numerical simulations have been done in the field of the flow around circular cylinders. Gu et al. (1994) found that vortex from one side of the cylinder to the other reach to a high degree of concentration of vorticity next to cylinder when the frequency ratio (ƒ/ ƒs) increased (ƒ the oscillating frequency of cylinder, ƒs is the shedding frequency for the fixed cylinder). Lu and Dalton (1996) studied the vortex shedding from a transversely oscillating circular cylinder in a uniform flow by numerical simulations. The effect of increasing the amplitude of an oscillating cylinder and the Reynolds number value are shown to lower the value of ƒ/ ƒs at which vortex switching.
In the present study, a three-dimensional numerical model has been developed, in order to study the sediment dynamics that occur in oscillatory flow over ripples. A morphology module has also been developed in order to perform two-dimensional simulations of the bed form evolution under hydrodynamic forcing. Results are presented for oscillatory flow over fixed ripples, at Reynolds number 23,163. The suspended sediment rise is highly correlated to the elevation of the flow vortices after their generation due to flow separation at the lee side of the ripples. The influence of the ripple height on the behaviour of suspended sediment is also significant. Concerning the evolution of the bed form, results of ripple creation, growth, merging, and annihilation are presented.
Surface waves in the coastal zone induce oscillatory flow motions in the vicinity of the seabed. These wave-induced coastal flows interact with the sandy seabed and modify the bed shape by generating coherent small-scale bed structures, which are generally known as ripples. The presence of ripples in oscillatory flows is important due to the impact they have on the seabed roughness. The bed roughness directly affects the near-bed boundary layer hydrodynamics, which in turn controls sediment transport in coastal areas. Consequently, accurate prediction of sediment transport rates is an important element in morphological studies in coastal marine environments.
In oscillatory flow over ripples, the behavior of suspended sediment is highly correlated to the development of the coherent vortices. During each half-cycle, vortices are generated at the lee side of the ripple. Sediment is first hurled over the lee vortex, and at flow reversal, carried with that vortex as it is ejected into the outer flow. According to this vortex formation – ejection mechanism, Bagnold (1946) characterized these bed forms as “vortex ripples”. Since then, vortex ripples have been observed both in experimental (Sleath, 1982; Sato et al., 1984; Osborne and Vincent, 1996; Fredsoe et al., 1999) and in numerical simulations (Sato et al., 1984; Blondeaux and Vittori, 1991; Hansen et al., 1994; Fredsoe et al., 1999; Zedler and Street, 2006).
During the last quarter of 2014, WTI crude oil price dropped precipitously from an average US$75 to a startling US$42. Production targets were difficult to achieve as the economic margin for well interventions narrowed. The revised objective was increasing oil production while minimizing investment cost and ensuring profitability of the well interventions. Identification of quick-win initiatives which required minimal investment to reactivate wells or increase their production included rig less interventions such as coiled tubing clean out campaigns and coiled tubing gas lift. Candidates which required heavy workovers were assessed through the RAPID process: R(eview) A(ssess) P(lan) I(mplement) D(iscuss). This process, though a part of our daily operations, was not aggressively implemented as oil prices further declined but was applied to the well review process to allow Petrotrin to be better prepared for more favourable oil prices. A revision to the economic feasibility of all well interventions was also re-evaluated to more lenient parameters. The estimated production from the quick-win initiatives was 500 bopd (unrisked) with a risked gain of (375bopd), whilst the estimated production increase from the application of the RAPID technique is expected the realize 1800 bopd (unrisked) with a risked production of 1080bopd. Well testing though significant, remained a challenge for proper evaluation of both the quick-wins and heavy workovers. In its absence Tubing Head Pressure (THP) and Line Pressure (LP) were monitored along with total transfer volumes at metering points to ensure expected gains were as was modelled. The economics of these projects were evaluated ensuring a Discounted Cash Flow Rate of Return (DCFROR) greater than 25%. Wells which did not meet the economic hurdle rate after the application of the RAPID technique were omitted pending more favourable oil prices, for cost optimization, Petrotrin proposes to implement the RAPID technique by project basis for operations such as fishing and well control for high pressure (HP) wells. Upon its approval, it would be included in the company's Standard Operating Procedure.
Historically, the marine systems on a Spar (ballasting, de-watering, ventilation, access, etc.) are relatively simple. However, attracted to the operational value of having large volumes of storage, particularly for flow assurance of the subsea wells and flowlines during shutdown conditions, the Gulfstar hull design criteria included the capabilities to store, inside the hull, 10,000 bbl of dead oil, 1,000 bbl each of diesel and methanol, all in integral carbon steel tanks, plus 2,400 bbl of subsea chemical in 18 individual stainless steel, vertical pressure vessels in both 100 and 200 bbl sizes. This took the Spar hull from being a relatively'unsophisticated' hull to something much more complex. The paper traces all the key process support and marine systems from their humble beginnings to their final form with all the Regulatory inputs and requirements which, in hindsight, turned out to be almost'a bridge too far.' After a short description of the systems with unique features and the regulations and design challenges behind them, the paper focuses on recommended changes for future projects, in addition to the obvious idea of radically simplifying those systems. As marine systems get more complex and projects try to introduce lower weight/lower cost/safer solutions ideas to optimize them, the existing Rules and Regulations can impede attempts to innovate in this area. As part of the lessons learned discussion, the paper speaks to the efficacy of risk-based design as compared to the traditional proscriptive/rules-based design approach as a way to accelerate innovation without compromising safety and operability. The information and results presented in this paper are applicable to engineers, class societies and regulators when trying to introduce more efficient process support and marine systems.
Methane hydrates have long been discussed as the next cradle of energy. Considered a resource of near infinite reserve potential, methane hydrates could supplant conventional hydrocarbon-based energy for the foreseeable future. In recent years there has been considerable activity in the petroleum industry to fully understand onshore and offshore hydrate deposits and methods of extraction and production; however, a commercial scale level has not been achieved. While there have been efforts to commercialize methane hydrate development in some parts of the world, the Gulf of Mexico remains relatively unexplored in this arena. This paper evaluates the economic viability of a commercial scale offshore methane hydrate production operation in the Gulf of Mexico-- by creating a sample capital cost budget.
In this paper we explore the West Africa-South America analogue proven by the Jubilee and Zaedyus discoveries in Ghana and French Guiana, respectively. Instead of the Turonian turbidite fan reservoirs, we consider younger unproven deep water channel systems in Foz do Amazonas Basin in Brazil which could be analogous to the Campanian pay found in the Teak field in Ghana. We present a geological overview of the basin together with acquisition details and imaging results of a regional 3D CSEM survey in the area. Using CSEM as a fluid indicator, we calculate the Net Rock Volume (NRV) from a channel-shaped EM anomaly and with conservative parameterization we obtain a P10/P90 ratio of 14.7 and an average NRV of ~23000hm3.
In September 2011 Tullow Oil announced a significant oil discovery in the Zaedyus prospect in French Guiana that established the Turonian aged Jubilee play from Ghana, West Africa. Following the Zaedyus discovery, a 2012-2013 drilling program of 4 exploration wells targeting nearby turbidites resulted in disappointing commercial success. We will discuss the potential of the younger channel play in the lower Tertiary and upper Cretaceous in Foz do Amazonas basin rather than the Turonian turbidite fans. Continuing the West Africa/South America analogue, the channel systems could resemble the Campanian pay of the Teak-1 exploration well in Ghana (Kosmos Energy, 2011). First, we will give an overview of the geology providing potential reservoir and trapping mechanisms. Second, we will use results of a regional multi-client 3D CSEM survey as a fluid indicator. Acquired in 2013, the survey is bordering French Guiana towards west within 15km of the last exploration well of the drilling program, GM-ES-5, and within 50km of the Zaedyus discovery. Third, we will use the method introduced by Baltar and Roth (2013) to estimate the Net Rock Volume in a sub-region of the CSEM coverage.
The present day shelf margin region of the Foz do Amazonas Basin has undergone significant modification from mass wasting events and debris flows. The basin provides analogous examples for deep water depositional systems in the underlying Tertiary and Cretaceous sections. Based on seismic observations, the shelf is shaped by the orientation of shallow basement that is interpreted as continental crust from potential field data. The basement extends outward from the coastline for approximately 130 kilometers before rapidly dropping off in a series of complex fault systems that are related to older rift stage graben systems.