Efficient Technology Application to Optimize Deep Gas Well Completions in the Khuff and Jauf Formations Requiring Hydraulic Fracturing in Saudi Arabia

2001 ◽  
Author(s):  
J. Ricardo Solares
Keyword(s):  
Saudi Arabia ◽  
Hydraulic Fracturing ◽  
Efficient Technology ◽  
Gas Well ◽  
Technology Application ◽  
Well Completions

Evolving Khuff Formation Gas Well Completions in Saudi Arabia: Technology as a Function of Reservoir Characteristics Improves Production

2013 ◽  
Author(s):  
Zillur Rahim ◽  
Hamoud Al Anazi ◽  
Adnan Al-Kanaan ◽  
Areiyando Makmun ◽  
Christopher N Fredd ◽  
...  
Keyword(s):  
Saudi Arabia ◽  
Gas Well ◽  
Reservoir Characteristics ◽  
Well Completions

Wettability Alteration to Intermediate Gas-Wetting in Gas-Condensate Reservoirs at High Temperatures

SPE Journal ◽  
2007 ◽  
Vol 12 (04) ◽  
pp. 397-407 ◽  
Author(s):  
Mashhad Mousa Fahes ◽  
Abbas Firoozabadi
Keyword(s):  
Hydraulic Fracturing ◽  
Production Rate ◽  
High Temperatures ◽  
Gas Production ◽  
Reservoir Rock ◽  
Wettability Alteration ◽  
Absolute Permeability ◽  
Low Permeability ◽  
Gas Well ◽  
Water Blocking

Summary Wettability of two types of sandstone cores, Berea (permeability on the order of 600 md), and a reservoir rock (permeability on the order of 10 md), is altered from liquid-wetting to intermediate gas-wetting at a high temperature of 140C. Previous work on wettability alteration to intermediate gas-wetting has been limited to 90C. In this work, chemicals previously used at 90C for wettability alteration are found to be ineffective at 140C. New chemicals are used which alter wettability at high temperatures. The results show that:wettability could be permanently altered from liquid-wetting to intermediate gas-wetting at high reservoir temperatures,wettability alteration has a substantial effect on increasing liquid mobility at reservoir conditions,wettability alteration results in improved gas productivity, andwettability alteration does not have a measurable effect on the absolute permeability of the rock for some chemicals. We also find the reservoir rock, unlike Berea, is not strongly water-wet in the gas/water/rock system. Introduction A sharp reduction in gas well deliverability is often observed in many low-permeability gas-condensate reservoirs even at very high reservoir pressure. The decrease in well deliverability is attributed to condensate accumulation (Hinchman and Barree 1985; Afidick et al. 1994) and water blocking (Engineer 1985; Cimolai et al. 1983). As the pressure drops below the dewpoint, liquid accumulates around the wellbore in high saturations, reducing gas relative permeability (Barnum et al. 1995; El-Banbi et al. 2000); the result is a decrease in the gas production rate. Several techniques have been used to increase gas well deliverability after the initial decline. Hydraulic fracturing is used to increase absolute permeability (Haimson and Fairhurst 1969). Solvent injection is implemented in order to remove the accumulated liquid (Al-Anazi et al. 2005). Gas deliverability often increases after the reduction of the condensate saturation around the wellbore. In a successful methanol treatment in Hatter's Pond field in Alabama (Al-Anazi et al. 2005), after the initial decline in well deliverability by a factor of three to five owing to condensate blocking, gas deliverability increased by a factor of two after the removal of water and condensate liquids from the near-wellbore region. The increased rates were, however, sustained for a period of 4 months only. The approach is not a permanent solution to the problem, because the condensate bank will form again. On the other hand, when hydraulic fracturing is used by injecting aqueous fluids, the cleanup of water accumulation from the formation after fracturing is essential to obtain an increased productivity. Water is removed in two phases: immiscible displacement by gas, followed by vaporization by the expanding gas flow (Mahadevan and Sharma 2003). Because of the low permeability and the wettability characteristics, it may take a long time to perform the cleanup; in some cases, as little as 10 to 15% of the water load could be recovered (Mahadevan and Sharma 2003; Penny et al. 1983). Even when the problem of water blocking is not significant, the accumulation of condensate around the fracture face when the pressure falls below dewpoint pressure could result in a reduction in the gas production rate (Economides et al. 1989; Sognesand 1991; Baig et al. 2005).

Casing Drilling Technology Application: Case Histories from Saudi Arabia

2012 ◽  
Author(s):  
Jude Chima ◽  
Shaohua Zhou ◽  
Ali Al-Hajji ◽  
Mike Okot ◽  
Qamar J. Sharif ◽  
...  
Keyword(s):  
Saudi Arabia ◽  
Case Histories ◽  
Technology Application ◽  
Drilling Technology ◽  
Casing Drilling

A Case Study of Hydraulic Fracturing Monitoring in Shale Gas Well Based on DAS

2021 ◽  
Author(s):  
S. An ◽  
X. Liang ◽  
G. Yu ◽  
D. Li ◽  
J. Wu ◽  
...  
Keyword(s):  
Hydraulic Fracturing ◽  
Shale Gas ◽  
Gas Well

Evolution of Hydraulic Fracturing Operations & Technology Applications in India

2021 ◽  
Author(s):  
Ravi Ramniklal Gondalia ◽  
Amit Sharma ◽  
Abhishek Shende ◽  
Amay Kumar Jha ◽  
Dinesh Choudhary ◽  
...  
Keyword(s):  
Hydraulic Fracturing ◽  
Service Providers ◽  
High Volume ◽  
Operational Strategies ◽  
Technology Application ◽  
The Past ◽  
Multi Stage ◽  
Technology Applications ◽  
Fit For Purpose ◽  
Reservoir Type

Abstract From 2005 to 2020, the application of hydraulic fracturing technology in India has touched the length and breadth of the country in almost every basin and reservoir section. The variety of reservoirs and operating environment present in India governed this evolution over the past 15 years resulting in a different fit for purpose fracturing strategy for each basin varying from conventional single-stage fracturing (urban, desert & remote forested regions) to high volume multi-stage fracturing, deepwater frac-packs and offshore ultra-HPHT fracturing. The objective of this paper is to present the milestones along this evolution journey for hydraulic fracturing treatments in India from 2005 to 2020. This paper begins with a review of published industry literature from 2005 to 2020 categorized by reservoir type and the proven economical techno-operational fracturing strategy adopted during that period. The milestones are covered chronologically since the success or failure of technology application in one basin often influenced the adoption of novel hydraulic fracturing methods in other basins or by other operators during the initial years. The offshore evolution is branched between the west and the east coasts which have distinctly different journeys and challenges. The onshore evolution is split into 5 categories: Cambay onshoreBarmer Hills & Tight GasEast India CBM and shale gasAssam-Arakan BasinOnshore KG Basin Each of these regions is at different stages of evolution. The Barmer region is in the most advanced state of evolution with frac factories in place while the Assam-Arakan Basin is in a relatively nascent stage. Figure 1 presents estimated hydraulic stage count based on published literature underlining the exponential growth in hydraulic fracturing activity in India. This paper enlists the technical and operational challenges present in the onshore and offshore categories mentioned above along with the identified novel techno-operational strategies which have proven to be successful for various operators in India. A comparison is presented of the different timelines of the exploration-appraisal-development journey for each region based on the economic viability of fracturing solutions available today in the Industry. Lastly, specific non-technical challenges related to available infrastructure, logistics and social governance are discussed for each region. This paper concludes by identifying the next step-change in the evolution of hydraulic fracturing operations in India among the 5 categories. Each of Government, operators and service providers have important roles to play in expanding the adoption of this technology in India. These roles are discussed for each identified category with the perspective of continuing the country's journey towards energy security.

Microseismic Magnitudes and b-Values for Delineating Hydraulic Fracturing and Depletion

SPE Journal ◽  
2017 ◽  
Vol 22 (05) ◽  
pp. 1624-1634 ◽  
Author(s):  
T.. Dohmen ◽  
J.. Zhang ◽  
L.. Barker ◽  
J. P. Blangy
Keyword(s):  
Hydraulic Fracturing ◽  
Qualitative Assessment ◽  
Williston Basin ◽  
Oil Well ◽  
B Values ◽  
Relative Contribution ◽  
Microseismic Activity ◽  
Shear Slip ◽  
Microseismic Events ◽  
Well Completions

Summary In 2014, Hess Corporation collected microseismic and hydraulic-fracturing data in a Bakken field trial near an existing oil well in the Williston Basin of North Dakota. In addition to monitoring the microseismic activity of the newly drilled offset-well completions, the field test delineated the depletion surrounding the original well by slowly repressurizing it. This repressurization induced shear-slip events, which preferentially delineated the depleted zone of the producer well, a process we call microseismic depletion delineation (MDD). By comparing the magnitudes of the depletion-related events to those that accompanied the new offset completions, we observe that higher magnitude microseismic events occur within the depleted interval. This paper offers an explanation for why higher magnitudes appear in the depleted zone and suggests that measuring magnitude statistics in the form of b-values can provide a qualitative assessment of the relative contribution of oil from completions along a wellbore.

Preventing gas migration after hydraulic fracturing using mud cake solidification method in HTHP tight gas well

2020 ◽  
Vol 23 (4) ◽  
pp. 450
Author(s):  
Jun Gu ◽  
Hangxian Gao ◽  
Pin Gan ◽  
Penghui Zeng ◽  
Jiahe Chen ◽  
...  
Keyword(s):  
Hydraulic Fracturing ◽  
Tight Gas ◽  
Gas Migration ◽  
Gas Well ◽  
Mud Cake
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