scholarly journals Insights on Geochemical, Isotopic, and Volumetric Compositions of Produced Water from Hydraulically Fractured Williston Basin Oil Wells

2021 ◽  
Author(s):  
Tanya J. Gallegos ◽  
Colin Doolan ◽  
Rodney Caldwell ◽  
Mark A. Engle ◽  
Matthew Varonka ◽  
...  
Keyword(s):  
Produced Water ◽  
Oil Wells ◽  
Williston Basin

scholarly journals Geochemical, Isotopic and Volumetric Signatures of Produced Water from Williston Basin Oil Wells Hydraulically Fractured with Crosslinked Gel

2020 ◽  
Author(s):  
Tanya J. Gallegos ◽  
Colin Doolan ◽  
Rodney Caldwell ◽  
Mark A. Engle ◽  
Matthew Varonka ◽  
...  
Keyword(s):  
Produced Water ◽  
Oil Wells ◽  
Williston Basin

Case Study of Artificial Lift Strategy Selection and Optimization for Unconventional Oil Wells in the Williston Basin

2018 ◽  
Author(s):  
Katherine Escobar Patron ◽  
Kathy Zhang ◽  
Tao Xu ◽  
Haidan Lu ◽  
Shihao Cui
Keyword(s):  
Oil Wells ◽  
Williston Basin ◽  
Strategy Selection ◽  
Unconventional Oil ◽  
Artificial Lift

scholarly journals New Technologies to Improve the Performance of High Water Cut Wells Equipped With ESP

2021 ◽  
Author(s):  
Sudad H Al-Obaidi ◽  
Smirnov VI ◽  
Khalaf FH
Keyword(s):  
New Technologies ◽  
Produced Water ◽  
Low Cost ◽  
High Water ◽  
Oil Wells ◽  
Simultaneous Injection ◽  
High Water Cut ◽  
Water Cut

The article deals with theoretical and practical issues of improving the efficiency of operation of high-water cut oil wells by developing and applying double-acting pumping systems based on electric submersible pumps. This combination is providing down-hole gravitational separation of oil and produced water, lifting low-water-cut oil to the surface with simultaneous injection of most of the separated water into the absorbing formation without lifting to the surface. Moreover, it is providing low-cost regulation of the ratio of the volumes of the lifted product and the injected water, as well as monitoring the quality of the injected water with the required frequency.

Characterization and Origin of Brines from the Bakken-Three Forks Petroleum System in the Williston Basin, USA

2017 ◽  
Vol 54 (3) ◽  
pp. 203-221 ◽  
Author(s):  
Zell Peterman ◽  
Joanna Thamke ◽  
Kiyoto Futa ◽  
Thomas Oliver
Keyword(s):  
Membrane Filtration ◽  
Meteoric Water ◽  
Produced Water ◽  
Major Ions ◽  
Williston Basin ◽  
Bakken Formation ◽  
Rock Interaction ◽  
Three Forks ◽  
Western North Dakota ◽  
Water Rock Interaction

Brine (also referred to as ‘produced water’) samples were collected from 28 wells producing oil from the Late Devonian-Early Mississippian Bakken and Three Forks Formations in the Williston Basin of eastern Montana and western North Dakota. The samples were analyzed for major ions, trace metals, stable isotopes, and strontium isotopes. The brines in these formations are highly saline with total dissolved solids averaging 308 g/L, almost ten times the salinity of modern seawater. Relative to modern seawater, the brines are enriched approximately 10 to 20 times in [Na], [K], [Cl], and [Br]. Greater enrichments of 100 to 400 times in [Li], [B], [Sr] and [Rb], and 2,000 to 10,000 times in [Cs] and [Ba] are probably due to water-rock interaction (WRI). WRI is further indicated by 87Sr/86Sr values typically between 0.710 and 0.711—considerably larger than marine values of 0.7081 to 0.7083 during this depositional interval. Bakken Formation sediments were deposited in a stratified water column with salinity increasing with depth. The deeper water may have been saturated in calcium carbonate and possibly gypsum, but there is no evidence that halite saturation had been attained. Therefore, brines may have been introduced into the Bakken Formation from the underlying Devonian Prairie Formation or from the overlying Charles Formation before these brines were diluted or replaced by meteoric water. Alternatively, salinity of the native pore water was increased by membrane filtration driven by overpressuring within the Bakken Formation.

scholarly journals Turbidity and oil removal from oilfield produced water, middle oil company by electrocoagulation technique

2018 ◽  
Vol 162 ◽  
pp. 05010
Author(s):  
Thamer Mohammed ◽  
Esraa Abbas ◽  
Thabit Ahmed
Keyword(s):  
Current Density ◽  
Oil Content ◽  
Produced Water ◽  
Oil Wells ◽  
Experimental Results ◽  
Allowable Limit ◽  
Current Densities ◽  
Oilfield Produced Water ◽  
Limit Effect ◽  
Oil Company

Huge quantity of produced water is salty water trapped in the oil wells rock and brought up along with oil or gas during production. It usually contains hydrocarbons as oil and suspended solids or turbidity. Therefore the aim of this study is to treat produced water before being discharge to surface water or re injected in oil wells. In this paper experimental results were investigated on treating produced water (which is obtained from Middle Oil Company-Iraq), through electrocoagulation (EC). The performance of EC was investigated for reduction of turbidity and oil content up to allowable limit. Effect of different parameters were studied; (pH, current density, distance between two electrodes, and electrolysis time). The experimental runs carried out by an electrocoagulation unit was assembled and installed in the lab and the reactor was made of a material Perspex, with a capacity of approximately 2.5 liters and dimensions were 20 cm in length, 14 cm in width and 16 cm height. The electrodes employed were made of commercial materials. The anode was a perforated aluminum rectangular plate with a thickness of 1.72 mm, a height of 60 mm and length of 140 mm and the cathode was a mesh iron. The current was used in the unit with different densities to test the turbidity removing efficiency (0.0025, 0.00633, 0.01266 and 0.0253 A/cm2).The experiment showed that the best turbidity removing was (10, 9.7, 9.2, 18 NTU) respectively. The distance between the electrodes of the unit was 3cm. The present turbidity removing was 92.33%. A slight improvement of turbidity removing was shown when the distance between the electrodes was changed from 0.5 to 3 cm with fixation of current density. The best turbidity removing was 93.5% , (7.79 NTU) when the distance between the electrodes were 1 cm. The experimental results found that concentration of oil had decreased to (10.7, 11.2, 11.7, 12.3) mg/l when different current densities (0.00253, 0.00633, 0.01266, 0.0253) A/cm2 were used, respectively with the distance between the electrodes was 3 cm. The best result of oil content decreasing was 10.7 mg/l with current density 0.0253 A/cm2. These results are within allowable limit to provide the possibility of reuse the water and can be injected in oil wells

Overcoming Obstacles for Produced Water in Bakken Well Stimulations

2015 ◽  
Author(s):  
Darren D. Schmidt ◽  
P.E.. E. Statoil ◽  
Bruce MacKay ◽  
Brandon Williams ◽  
Frederick Beck ◽  
...  
Keyword(s):  
Produced Water ◽  
Technology Development ◽  
Williston Basin ◽  
Bakken Formation ◽  
Well Stimulation ◽  
Three Forks ◽  
Technical Issues ◽  
Fluid Design ◽  
Hybrid Fluid

Abstract The use of produced water in well stimulation is not straightforward and presents numerous challenges. A case study using 100% produced water from the Bakken Formation to stimulate a two-well pad in Williams County North Dakota is presented. The well stimulations include a typical 30-stage plug & perf completion using a hybrid fluid design consisting of slickwater and crosslinked gel. The pad includes both a Middle Bakken horizontal and a Three Forks horizontal well. This case study addresses the challenges and obstacles faced over a two-year period since embarking on the first field experiment using 50% produced water to stimulate a well in the same area. A number of first-time experiences have been addressed in the areas of cost, fluid chemistry, water quality, facilities, logistics, storage, and regulatory. All of these factors appeared to be insurmountable barriers in the early phases of considering the use of produced water for well stimulation. However over time and with careful developments along the way, we have progressed to the point of practicality for such endeavors. This case study presents the barriers, technical issues, technology development, current practice, and expected progress of produced water stimulation in the Williston Basin.

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