Sand management has become in one of the most vital factors in today's upstream oil and gas industry, more and more are the cases where the sand control systems play an important factor to determine the economic viability of each project. This paper will focus in a solution for sand problems in ESP systems applying to sand slug breakdown using a 10 V-Mesh Sand Screen to homogenize the solid inflow in the system so it would be easier to handle the solids through the ESP's stages. The implementation of the screen intake for the homogenization of solids in an ESP well allowed to efficiently manage sand slugs, improving the pump efficiency and avoiding blocking problems in the pump caused by sand. Furthermore, the system allows increasing the frequency of operation of the ESP motor to have a greater drawdown, increasing the production of the fluid from 1600 BFPD to 1800 BFPD. The behavior of the sensor data such as vibration, current, and voltage remained stable throughout the period evaluated, extending the run life of the system.
SPE is educating the next generation of aspiring engineers, scientists and managers about the oil and gas industry. This is an opportunity for school students in grades 9–12, studying Mathematics, Physics, Chemistry, Geography or interested in Petroleum Engineering are invited to join SPE members from all over the globe to discover the world of Petroleum Engineering. School teachers are invited to bring a group of 10–15 students. Students will be treated to a range of hands-on activities and presentations from renowned engineers. The oil price outlook coupled with the response of each oil and gas company to make ends meet has led to severe exploration budget cuts.
The availability of high quality seismic data is of critical importance in trying to unravel the complexities of subsurface geology. This paper illustrates how proper selection of seismic acquisition parameters and data processing techniques can successfully overcome geological difficulties and minimize uncertainties when exploring for hydrocarbons in the northern part of Block G11/48, Gulf of Thailand, without compromising safety and cost efficiency.
Fluvial and fluvio-deltaic sediments of early to mid Miocene age in low relief faulted structural traps constitute the most common hydrocarbon habitat in the area of investigation. Amplitude support in identifying potential targets is also proven by nearby discoveries. To fully evaluate the exploration potential of this area, a 3D seismic acquisition campaign was successfully carried out using a high-end seismic vessel and without HSSE incidents.
The Nong Nuch dataset was acquired using a 10 deep-flat towed 5.1 km streamer configuration with triple sources to increase cross-line resolution and reduce operational time. This long streamer length relative to the target depth provides necessary information to Full Waveform Inversion and Q-tomography in order to correct push-down effects in broadband anisotropic Pre-stack Depth migration. The dataset also helps to obtain high accuracy velocity model, de-multiple and quantitative interpretation. This acquisition and processing approach significantly improved the ability to image thin reservoirs and correct push-down effects and energy absorption due to gas clouds or unconsolidated sea floor channels.
The large streamer spread and deep tow did not create any major problems throughout the acquisition. The implementation of broadband acquisition and leading edge processing techniques resulted in good signal to noise ratio as well as high vertical and horizontal resolution with minimal acquisition footprint. In addition, long offset data acquisition contributes to successful attenuation of short and long period multiples. Channel-like features and fault plane reflections are very clearly imaged in the dataset, helping to better understand of the depositional environment and structural setting of the area. Severe push-down and abnormal amplitude absorption effects were significantly corrected and compensated by building a high resolution, Full Waveform Inversion (FWI) derived velocity model as well as application of reflection tomography and Q-tomography techniques. Thus, definition of potential traps beneath gas clouds has significantly improved.
Tongkum, Tossapol (Mubadala Petroleum) | McManus, Ian (Mubadala Petroleum) | Abu-Jafar, Feras (Mubadala Petroleum) | Thanasarnpisut, Viraphon (Schlumberger) | Vargas Bermea, Jorge Andres (Schlumberger) | Kaewpraphan, Kingkarn (Schlumberger) | Wuttikamonchai, Pakaporn (Schlumberger)
Lost circulation, while cementing, compromises the objectives of cementing an oil or gas well. Losses encountered during cementingcan cause a weak casing shoe, poor zonal isolation, early water breakthrough for an oil producer, as well as increasing the possibility of costly intervention work. Execution of primary cementing operations can be subject to unplanned circumstances; when a slurry is being pumped or displaced and losses are recorded, in most circumstances the operation switches to damage limitation by slowing down the pumping rate.
The Nong Yao field (
Nong Yao field localization
Nong Yao field localization
To overcome the challenges, an "out of the box" approach was essentialwhich yielded two innovative solutions: i) a combination of advanced lightweight cementwith engineered reticular fiber (ERF) systems, which allows safer placement of the cement in the annulus, while minimizing the potential losses; ii) a combination of several lost circulation materials (LCM) in an optimized ratio in an engineered fiber-basedlost circulation weighted spacer package, which has an additional function of preventing and mitigating risk of losses during cementing. This approach was intended to reinforce the loss zones by using the four-step methodology; disperse, bridge, plug and sustain. The severity of lost circulation while cementing was significantly reduced without compromising the abovementioned objectives.
This paper will discuss the successful implementation of the new approach solution by integrating different technologies to overcome the challenges of unpredictable losses during cementation. Two case histories from numerous jobs will be discussed with cement post-job evaluation via playback simulations and standard cement bond logs, which validates that the new approach increases the chance of achieving well objectives. Consequently, the risk of unplanned (UNP) operations and costly remedial operations are substantially reduced.
This review of technical challenges facing oil and gas producers in the Gulf of Thailand arose from last month's meeting in Bangkok, Thailand, of the SPE Board of Directors with the SPE Asia Pacific Advisory Council, which is represented by senior executives from across the Asia Pacific region and industry value chain. It was an opportunity for Board members to meet with the leadership of the major oil and service companies and discuss how best the SPE can serve its membership in the region. The SPE Board of Directors meets three times per year. One meeting is held in conjunction with the SPE Annual Technical Conference and Exhibition (ATCE), usually during September or October; the other meetings are held in locations around the world chosen for strategic reasons by the SPE President. Thailand is an oil and natural gas producer.
Chigbo, I. T. (Mubadala Petroleum) | Opdal, S. T. (Mubadala Petroleum) | Tarasombut, P. (Mubadala Petroleum) | Gordon, G. (Schlumberger) | Rekijtisirikul, N. (Schlumberger) | Duangprasert, T. (Schlumberger) | Ridho, M. (Schlumberger) | Roumi, M. (Schlumberger) | Woiceshyn, G. E. (Absolute Completion Technologies/Schlumberger) | Wells, D. G. (Absolute Completion Technologies/Schlumberger)
The production strategy in the Nong-Yao field considered the unconsolidated nature of the reservoirs and an effective drawdown strategy given the use of Electrical Submersible Pump (ESP) for artificial lift. The particle size distribution analysis demonstrated a broad range of sand grain size that would ideally require sand control methods like gravel packing which was not preferred due to cost and complexity. A simpler and cost-effective solution using an advanced sand screen technology was implemented. Applying a minimum drawdown across horizontal inflow across the sand face via gradual increase of ESP frequency was initially adopted to complement the use of screen only completion.
The specially designed sand screen with compressed metal-wool was installed in 14 wells in the Nong Yao field. All wells were completed with ESP for artificial lift. After one year of production, the wells have produced sand free with no sand observed at surface, even though some wells are high water-cuts and ESP frequencies have been ramped up. Analysis performed using downhole ESP pressure data indicate very low draw-down across the sand face, suggesting no issues with downhole plugging of the screens. This observation shows that the implemented completion design, along with the production start-up strategy is working well. This same strategy is being applied in the next phase of the field development.
This is the first application of the compressed metal-wool sand screen in the Gulf of Thailand. The analysis and deployment of this sand control method to fit the reservoir sand characteristics, in combination with artificial lift and production strategy to meet operational challenges, to reduce development cost and to achieve production performance. The success achieved with this in the Nong Yao field could be extended to other marginal field developments, which have similar sand face completion challenges.
Wilkins, M (Mubadala Petroleum Thailand) | Pambayuning, S (Mubadala Petroleum Thailand) | Watcharanantakul, R (Mubadala Petroleum Thailand) | Thepparak, S (Mubadala Petroleum Thailand) | Opdal, S (Mubadala Petroleum Thailand) | Teeratananon, W (Mubadala Petroleum Thailand) | Chigbo, I (Mubadala Petroleum Thailand) | Santoso, G (Schlumberger) | Thanh, P Nguyen (Schlumberger) | Doogue, J (Schlumberger) | Park, W (Schlumberger) | Khunaworawet, T (Schlumberger) | Ridho, M (Schlumberger) | Foongthingcharoen, T (Schlumberger) | Rehman, S (Schlumberger)
The Nong Yao field is operated by Mubadala Petroleum on behalf of the G11/48 block concessionaires with KrisEnergy and Palang Sophon Limited. Nong Yao recently commenced production following a successful development drilling campaign, which was extremely challenging due to subsurface uncertainties. The subsurface team adopted an innovative method of well sequencing and optimization of targets, such that every well drilled is used to de-risk other wells, in order to avoid costly additional appraisal drilling.
The key methodology involved a deep understanding of the exploration and appraisal data gaps and as a result the uncertainties / limitations of the static and dynamic models. A field development plan was developed that could achieve additional appraisal objectives, and in doing so, de-risk other wells as the development was executed. Uncertainties that the team sought to mitigate included structural uncertainty (due to shallow gas effects), fluid contacts and fluid type uncertainty, sand distribution and connectivity uncertainty and also uncertainty in the aquifer extent and degree of pressure support expected. This information was gathered by planning deeper high deviation development wells with complex 3D trajectories, that could intersect multiple reservoir sands and provide the formation evaluation and well landing points for later horizontal development wells in shallower reservoirs.
Achieving appraisal objectives while drilling both in the static and dynamic sense, helped in optimizing well locations and led to the cancellation of multiple water injection wells, which were not required as drilling indicated better aquifer and pressure support than initially expected. This led to substantial savings in well costs and enabled rig slots to be utilized for production wells rather than unnecessary injection wells. Key technologies were used to achieve appraisal objectives. A high build rate hybrid RSS tool was used to deliver complex 3D well profiles and land wells above oil-water contacts while maintaining high ROP and wellbore quality. The deep resistivity distance to boundary LWD tool ensured horizontal production wells stayed in the reservoir sands and also helped to map the top and extent of structures, improving reserve calculations and reservoir simulation. In key wells the use of ultra-deep resistivity for reservoir mapping combined with the LWD near-bit triple combo, helped in mapping the reservoir prior to entering it, eliminating the requirement for separate pilot wells. Innovative formation pressure acquisition methods were used to better understand reservoir connectivity and depletion and to determine whether injection wells were required. It also helped to reduce uncertainty on fluid contacts, providing better accuracy and optimizing well positioning. The impact was that more marginal oil pools could be developed with a higher degree of confidence. The clear value of these innovations was a reduced overall development cost and wells better placed for recovery and production. With lower development costs, more reservoirs of this nature in the Gulf of Thailand can become viable to develop, which has a significant impact on the future of Thailand's oil and gas industry.