Use of Cross-Linked Polymer Systems to Improve Volumetric Sweep Efficiency and Alternative Full Field Development Strategy for a Mature Waterflooding Optimization Processes - Dina Cretaceous Field Case

2018 ◽  
Author(s):  
J. M Leon ◽  
M. Izadi ◽  
A. Castillo ◽  
J. F. Zapata ◽  
C. Chaparro ◽  
...  
Keyword(s):  
Development Strategy ◽  
Sweep Efficiency ◽  
Full Field ◽  
Polymer Systems ◽  
Field Case ◽  
Field Development ◽  
Waterflooding Optimization

Successful Unconventional Fracturing Tight and Highly Laminated Silicilyte Reservoir Leading to Economic Field Development

2021 ◽  
Author(s):  
Alexey Moiseenkov ◽  
Dmitrii Smirnov ◽  
Abdullah Al Hadhrami ◽  
Pankaj Agrawal ◽  
Amira Harrasi ◽  
...  
Keyword(s):  
Development Strategy ◽  
Oil Production ◽  
Commercial Production ◽  
Full Field ◽  
Field Development ◽  
Chemical Tracers ◽  
Vertical Permeability ◽  
To Come ◽  
Development Approach ◽  
Sonic Logging

Abstract South Oman contains several tight silicilyte reservoirs with significant locked hydrocarbon volumes. Successful hydraulic fracturing is key for unlocking commercial production. Low production rates coupled with fast declines have remained a challenge and a new economically attractive development scheme was required. Through integrated re-evaluation of the geology and reservoir, a modified frac approach was designed to create more connectivity to the reservoir height, using an unconventional frac design and frac fluids plus over-flush. Poor well productivity in tight silicilyte reservoir can be explained by low permeability of 0.001-0.1 mD and laminated texture with almost zero vertical permeability. Fit for purpose modelling was performed to assess the forecasting range for sub-surface uncertainties and frac parameters. One of the key changes for a successful development strategy was to place a higher number of fracs to overcome the extreme lamination. [1] It was observed that the "conventional" fracturing approach inaccurately assumed higher vertical fracture coverage of the reservoir and that the guar fluid used was much more damaging due to low recovery after frac clean-up. Fifteen unconventional fracs were pumped successfully with over-flush pumping technique. To understand if this new unconventional approach was effective in overcoming the extreme lamination required additional understanding of fractures geometry and orientation. To confirm fracture dimensions and flowing heights; a set of radioactive, chemical tracers and logging activities were completed. Flowback results showed that the unconventional frac [3] fluid used, was relatively easy to recover from formation and better cleaning-up of fractures can be achieved. This led to successful well clean-up compared to previous wells in the same field and confirmed better fracs clean up. Initial production results confirmed at least double well initial productivity, which should lead to better stable oil production from the field. Radioactive tracers logging, Sonic logging and Spectrum Noise Logging (SNL) confirmed mechanical and conductive fracture heights. Sonic logging also confirmed frac orientation. Oil and water dissolvable tracers confirmed fractures clean up from water and oil production intervals. Full geological and reservoir understanding, out of box thinking in frac technology allowed the asset team to come up with an unconventional development approach to improve commercial production from tight silicilyte reservoirs. The new frac approach included unconventional frac design and fluids, and execution using over flush and resulted into unlocking significant reserves. A more economic full field development is being planned and replication of the new frac approach is already ongoing in other fields.

Unlock Condensate Reserves by Peripheral Development of Giant Condensate

2021 ◽  
Author(s):  
Nouf Sulaiman Al Yaaqoubi ◽  
Zainah Salem Al Agbari ◽  
Maxim Sudarev ◽  
Eduard Latypov ◽  
Ihab Nabil Mohamed ◽  
...  
Keyword(s):  
Simulation Modeling ◽  
Gas Production ◽  
Gas Condensate ◽  
Sweep Efficiency ◽  
Full Field ◽  
Field Development ◽  
Expected Gain ◽  
Peripheral Area ◽  
Condensate Reservoir ◽  
Future Prediction

Abstract This paper addresses the development of peripheral area in order to maximize the condensate production in a giant Recycle Gas-Condensate Reservoir in UAE. The condensate reservoir is producing many years under recycling mode to maintain the pressure and maximize the gas condensate recovery. The producers and injector wells are in a line drive pattern where the injected fluid is lean gas to maintain 100% VRR. The condensate production declined through the years due to gradual pressure decrease as well as injected lean gas/N2 breakthrough. Several studies were done to increase condensate recovery and extend gas production plateau. The methodology adopted for this study is the developing of the peripheral area in the giant recycle reservoir as part of its full field development plan (FFDP) in order to provide more pressure support initially and to increase the sweep efficiency for more condensate recovery. In addition; it is worth to mention that peripheral wells will provide production relaxation from some gas produces which have lean gas and N2 breakthroughs. Pilot wells were drilled to examine and confirm the strategy assumed by analyzing the performance of those wells in terms of location, condensate production, CGR values and trajectory. Simulation modeling was as well used for matching purposes and future prediction and forecasting. Pilot wells were drilled in deferent peripheral area in the reservoir and completed as horizontal gas producers. By analyzing the current wells performance it has been approved that the wells are producing high condensate about (2000-2500) MMstb and producing high CGR values about (80-100). Simulation modeling were utilize for future prediction and confirmed that the development of peripheral area by drilling additional wells enhances the sweeping efficiency and participated in expected gain a multimillions of barrels of additional condensate with maintaining the same business plan gas production target. It was promising to have more incremental in case of ramping up the production. The paper discussed in detail about methodology adopted in order to unlock the condensate reserves by peripheral development and confirmed the results of the gain of condensate production and CGR from actual data and simulation modeling. The provided information is quite informative to be widely used and applied in similar reservoirs.

Offshore Gas Field Development Strategy and Flow Assurance Prediction and Optimization in Harsh Environment

2018 ◽  
Author(s):  
Humoud Almohammad ◽  
Abdullah Al-Derbass ◽  
Abdulaziz Alsubaie ◽  
Mohammed Bumajdad ◽  
Abdulaziz Al-Khamis ◽  
...  
Keyword(s):  
Development Strategy ◽  
Harsh Environment ◽  
Flow Assurance ◽  
Gas Field ◽  
Field Development

scholarly journals The Waitsia Field, onshore North Perth Basin, Western Australia

2016 ◽  
Vol 56 (1) ◽  
pp. 29 ◽  
Author(s):  
Neil Tupper ◽  
Eric Matthews ◽  
Gareth Cooper ◽  
Andy Furniss ◽  
Tim Hicks ◽  
...  
Keyword(s):  
Flow Characteristics ◽  
Development Planning ◽  
Upper Permian ◽  
Depth Interval ◽  
Lower Permian ◽  
Minimal Processing ◽  
Gas Field ◽  
Full Field ◽  
Field Development ◽  
Primary Porosity

The Waitsia Field represents a new commercial play for the onshore north Perth Basin with potential to deliver substantial reserves and production to the domestic gas market. The discovery was made in 2014 by deepening of the Senecio–3 appraisal well to evaluate secondary reservoir targets. The well successfully delineated the extent of the primary target in the Upper Permian Dongara and Wagina sandstones of the Senecio gas field but also encountered a combination of good-quality and tight gas pay in the underlying Lower Permian Kingia and High Cliff sandstones. The drilling of the Waitsia–1 and Waitsia–2 wells in 2015, and testing of Senecio-3 and Waitsia-1, confirmed the discovery of a large gas field with excellent flow characteristics. Wireline log and pressure data define a gross gas column in excess of 350 m trapped within a low-side fault closure that extends across 50 km2. The occurrence of good-quality reservoir in the depth interval 3,000–3,800 m is diagenetically controlled with clay rims inhibiting quartz cementation and preserving excellent primary porosity. Development planning for Waitsia has commenced with the likelihood of an early production start-up utilising existing wells and gas processing facilities before ramp-up to full-field development. The dry gas will require minimal processing, and access to market is facilitated by the Dampier–Bunbury and Parmelia gas pipelines that pass directly above the field. The Waitsia Field is believed to be the largest conventional Australian onshore discovery for more than 30 years and provides impetus and incentive for continued exploration in mature and frontier basins. The presence of good-quality reservoir and effective fault seal was unexpected and emphasise the need to consider multiple geological scenarios and to test unorthodox ideas with the drill bit.

Cardiac Elastography, Full-Field Development

2008 ◽  
pp. 506-513
Author(s):  
Tomy Varghese ◽  
Q Chen ◽  
P Rahko ◽  
James Zagzebski
Keyword(s):  
Full Field ◽  
Field Development

scholarly journals Integrated Halo Model And Hydrodynamic Simulation For Optimization Oil Production In Crystalline Fractured Reservoirs

2021 ◽  
Author(s):  
Hung Vo Thanh ◽  
Kang-Kun Lee
Keyword(s):  
Oil Recovery ◽  
History Matching ◽  
Fractured Reservoirs ◽  
Petroleum Industry ◽  
Oil Production ◽  
Modelling And Simulation ◽  
Development Plan ◽  
Sweep Efficiency ◽  
Field Development ◽  
The World

Abstract Basement formation is known as the unique reservoir in the world. The fractured basement reservoir was contributed a large amount of oil and gas for Vietnam petroleum industry. However, the geological modelling and optimization of oil production is still a challenge for fractured basement reservoirs. Thus, this study aims to introduce the efficient workflow construction reservoir models for proposing the field development plan in a fractured crystalline reservoir. First, the Halo method was adapted for building the petrophysical model. Then, Drill stem history matching is conducted for adjusting the simulation results and pressure measurement. Next, the history-matched models are used to conduct the simulation scenarios to predict future reservoir performance. The possible potential design has four producers and three injectors in the fracture reservoir system. The field prediction results indicate that this scenario increases approximately 8 % oil recovery factor compared to the natural depletion production. This finding suggests that a suitable field development plan is necessary to improve sweep efficiency in the fractured oil formation. The critical contribution of this research is the proposed modelling and simulation with less data for the field development plan in fractured crystalline reservoir. This research's modelling and simulation findings provide a new solution for optimizing oil production that can be applied in Vietnam and other reservoirs in the world.

Iterative modeling is as a tool for selecting a geological basis for hydrodynamic modeling and development design

2021 ◽  
pp. 111-126
Author(s):  
A. A. Agarkova ◽  
S. E. Shebankin ◽  
M. A. Tukaev ◽  
M. S. Karmazin
Keyword(s):  
Initial Data ◽  
Hydrodynamic Modeling ◽  
Usual Method ◽  
Gas Condensate ◽  
Digital Model ◽  
Geological Model ◽  
Field Case ◽  
Field Development ◽  
Wide Range

The usual method for constructing a digital model of a field is based on hydrodynamic modeling using the basic implementation of a geological model, usually requires additional adjustments to the initial data, and as a result, leads to a wide range of uncertainties in assessing the predicted technological indicators of field development. The PK1 reservoir of a gas condensate field case study discuss-es the method of iterative modeling, which makes it possible to comprehensively approach the assessment of possible uncertainties.

Achieving Cementing Improvement in Horizontal Tight Gas Field Development

2015 ◽  
Author(s):  
Pungki Ariyanto ◽  
Mohamed.A.. A. Najwani ◽  
Yaseen Najwani ◽  
Hani Al Lawati ◽  
Jochen Pfeiffer ◽  
...  
Keyword(s):  
Tight Gas ◽  
Cement Slurry ◽  
Tight Sandstone ◽  
Gas Field ◽  
Full Field ◽  
Field Development ◽  
Horizontal Drain ◽  
Tight Reservoir ◽  
Design For All ◽  
Zonal Isolation

Abstract This paper outlines how a drilling team is meeting the challenge of cementing a production liner in deep horizontal drain sections in a tight sandstone reservoir. It is intended to show how the application of existing technologies and processes is leading to performance gain and improvements in cementing quality. The full field development plan of the tight reservoir gas project in the Sultanate of Oman is based on drilling around 300 wells targeting gas producing horizons at measured depths of around 6,000m MD with 1,000m horizontal sections. Effective cement placement for zonal isolation is critical across the production liner in order to contain fracture propagation in the correct zone. The first few attempts to cement the production liner in these wells had to overcome many challenges before finally achieving the well objectives. By looking at the complete system, rather than just the design of the cement slurry, the following criteria areas were identified: –Slurry design–Mud removal and cement slurry placement–Liner hanger and float equipment Improvements have been made in each of these areas, and the result has been delivery of a succesfully optimised liner cementing design for all future horizontal wells.

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