Ultrastrong Formations: Perforating Challenges, Limits, and Optimization

Mustafa, Hanaey Dandarawy; Briner, Andreas; Jumaat, Mohd Shafie; Grove, Brenden Michael; Atwood, David C.; Judd, Tobias Conrad

doi:10.2118/159771-ms

Cited by 8 publications

(1 citation statement)

References 4 publications

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“…Scratch test results (Fig. 12) were subsequently used for the tests of various explosive perforation charges (Mustafa et al 2012) and fracturing design for constructing stress profiles. …”

Section: Core and Rock Mechanicsmentioning

confidence: 99%

From Exploration to Production in 4 Years: Industry Collaboration Leading to Accelerated Learning Curve for Large Tight Gas Project in the Sultanate of Oman

Riyami¹,

Briner²,

Elliott³

et al. 2015

Day 1 Mon, November 09, 2015

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A large, strategically important unconventional (tight) gas project in the Sultanate of Oman advanced from the exploration stage with one discovery well to the pilot and development stages over 4 years. Project challenges in the first 2 years of exploration were poor initial success in both fracturing treatment placement and subsequent productivity and an ever-expanding scope of work in a demanding environment with limited resources. To address these challenges, the focus was shifted from routine delivery to an integrated approach and a strategy that included defined activity timelines, key performance indicators aligning with different stakeholders, and process reviews. Technology deployment and improved operations with allocated fracturing equipment spread gave flexibility to this new efficiency model. Integrated technology trials included cased and openhole completions; different well types; and several rock and core mechanical tests, such as reservoir coring, openhole stress testing, sonic measurements, and continuous unconfined compressive strength measurements. It also incorporated abrasive perforating, various fracturing treatment type designs, and advanced evaluation techniques such as microseismic monitoring, three-phase flow metering, tracers, and others. These technologies were implemented in a fast and efficient manner owing to strong collaboration between a dedicated Petroleum Development Oman (PDO) subsurface team and the service provider expertise. Personnel embedded in the exploration team greatly helped with linking to proper resources within the suppliers. An embedded engineer provided immediate technical and logistical support to the team. The improved process involved multiwell fracturing, a test campaign, and evaluation of individual zones. Finally, gaps and areas for improvement going forward were identified. Over the 4 years, with implementation of the new technology and strategy, the success rate of fracture placement and zonal evaluation increased from the low initial success of less than 50% to 100%; the improvement was particularly evident in the extremely tight lower intervals of the reservoir.

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“…Scratch test results (Fig. 12) were subsequently used for the tests of various explosive perforation charges (Mustafa et al 2012) and fracturing design for constructing stress profiles. …”

Section: Core and Rock Mechanicsmentioning

confidence: 99%

From Exploration to Production in 4 Years: Industry Collaboration Leading to Accelerated Learning Curve for Large Tight Gas Project in the Sultanate of Oman

Riyami¹,

Briner²,

Elliott³

et al. 2015

Day 1 Mon, November 09, 2015

Self Cite

View full text Add to dashboard Cite

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Drilling and Completion Challenges for Deep, Tight Gas Exploration Wells Onshore Northern Oman

Zerbst¹,

Al-Habsi²

2013

SPE Unconventional Gas Conference and Exhibition

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Since the late 1990ies Petroleum Development Oman L.L.C. (PDO) is actively exploring for tight gas onshore in the North of the Sultanate of Oman. Recent focus is on exploration targets in clastic formations in the Fahud and Ghaba basins with currently three drilling rigs dedicated to these activities. Most of the wells are deep (TD >5000 m TVDbdf [>16,000 ft TVDbdf]), in H P/HT (High Pressure/High Temperature) environments (even extreme HT >175 o C [350 o F] in some cases, Maldonado et a l. 2006) and need to be stimulated by hydraulic fracturing in several stages for evaluation (with fracture gradients up to 31 kPa/m [1.4 psi/ft]). This paper presents the associated challenges faced for well and completion designs including:  Exploration targets overview.  Uncertainties in reservoir properties.  Selected drilling aspects (well trajectory, casing scheme, cement bond, drill-in fluid, formation evaluation).  Completion design for deep, tight gas exploration wells (tubing sizing, material selection, cemented completions, tubular stress analyses [load case simulations], perforating, other).  Areas for potential future optimization and cost savings.Design experiences gained during the last two years and optimization steps implemented for these deep, tight gas exploration wells will be shared.

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Hard Formation Durability Gains 14% Footage and Replaces 2.7 Bits Versus Offsets

Cuillier¹,

Mangeny²,

Jelly³

et al. 2015

Day 4 Thu, November 12, 2015

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A specially designed diamond impregnated bit set new performance records in its initial application in a hard, abrasive Oman formation. Built for turbine drilling in the formation's sandstone-siltstones-shale, the 212.72-mm (8 3/8-in) bit drilled 588 m (1929 ft) in a single run, increasing footage drilled by 14% compared to the previous-best 8 3/8-in. run with a ROP of 2.02 m/hr (6.6 ft/hr). This performance replaced 2.7 bits through increased footage drilled and drill out capabilities. When the bit was pulled due to the BHA it was dull-graded: 3-2-WT-A-X-1-LM-BHA. The bit developed for the Oman run was a matrix body with 16 blades. Maximum durability and performance in the high-compressive strength formation was addressed with diamond-impregnated blocks on each blade and thermo/abrasion resistant PDC cutters in the bit center. Extreme drilling conditions presented by the turbine application and formation led to an optimized impregnated segment block geometry to maximize bit durability without impacting efficiency, and a change in hydraulics to maximize cooling and cleaning of the cutting faces. This paper is the first published examination of the diamond impregnated bit design process and resulting field experience in the Oman application. The study discusses the basis of the bit design and considerations in achieving operator objectives, including drilling as much footage as possible from 4190 m (13,743 ft) measured depth, while maintaining an average ROP of 2 to 2.5 m/hr (6.5 to 8.2 ft/hr). The authors examine the role of modeling and design software in optimizing durability and penetration rate in the hard formation, and they review enabling manufacturing and material advances.

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Ultrastrong Formations: Perforating Challenges, Limits, and Optimization

Cited by 8 publications

References 4 publications

From Exploration to Production in 4 Years: Industry Collaboration Leading to Accelerated Learning Curve for Large Tight Gas Project in the Sultanate of Oman

From Exploration to Production in 4 Years: Industry Collaboration Leading to Accelerated Learning Curve for Large Tight Gas Project in the Sultanate of Oman

Drilling and Completion Challenges for Deep, Tight Gas Exploration Wells Onshore Northern Oman

Hard Formation Durability Gains 14% Footage and Replaces 2.7 Bits Versus Offsets

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