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.

A large, strategically important tight gas project in the Sultanate of Oman progressed over 5 years on an accelerated path from exploration to the development stage. Collaboration between operator and service provider helped advance the deployment of technology that made this acceleration possible. Poor initial success in both hydraulic fracturing treatment placement and hydrocarbon productivity along with limited resources with ever-expanding work scope were the main challenges faced in the first 2 years of exploration. To address these challenges, an integrated approach to the project was taken. Technology trials and the selective deployment of technology along with improved operations gave flexibility to this new efficiency model. Close collaboration with the service provider allowed smoother and faster progress. Collaboration included joint technology mapping exercises, team visits to North American locations of the operator and the service provider with the goal of knowledge sharing, faster technology transfer, and the secondment of a senior engineer from the service provider as a full-time production technologist to the operators' subsurface team. The effective execution of strategy and implementation of various technologies resulted in an increase in the success rate of fracture placement and zonal evaluation from the initially low 50% to 100%. The integration of several disciplines was critical to achieving this goal. Technologies deployed in the project comprised of rock and core mechanical tests, such as reservoir coring, openhole stress testing, sonic measurements, continuous unconfined compressive strength measurements, abrasive perforating, various fracturing treatment designs, and several geomechanical studies targeting different aspects of fracture initiation. An additional focus was on the assessment of fracture geometry using radioactive tracers, advanced sonic logging, geomechanical evaluation coupled with geological mapping, microseismic monitoring, and cutting-edge fracture design methodology in both vertical and horizontal wells. The collaborative efforts led to evaluation of similarities and differences between North American and international unconventional projects and suggested techniques and best practices that can be applied in the tight gas project in the Sultanate of Oman. This project has been deemed one of the first commercially successful gas deliveries in the Middle East from a tight gas reservoir. Technologies, methods, and strategies developed for this large tight gas project and tested in the field will contribute to improving the success rate on similar projects around the world.

Oman's rapid domestic demand growth for gas, primarily for power generation, significant LNG sales contracts, and the petrochemical industry, will be met in the near future with a decline in conventional gas production. The supply shortfall may be met by Tight and Unconventional Gas, with its large volumes and long-term potential. To secure mid-long term supply Petroleum Development Oman (PDO) is executing an appraisal programme in North Oman focussing on the Amin Fahud Basin Tight Gas sandstones with porosities ranging from 3 to 10% and (ambient) permeabilities from 0.001 to 1 mD.Target reservoirs pose significant technical challenges summarised in being deep (4500-5000 m / 15,000-16,500 ft) and have high reservoir temperatures (170 to 180°C / 300 to 360F) and the rocks are tectonically stressed which manifests itself in high fracture gradients above the overburden stress. On top of all this, longer term well production will be impacted by relatively high CGRs and associated water production.To commercialise these reservoirs an integrated ring-fenced team is tasked to unlock these reservoirs potential. Key commercialisation factors include; ultimate recovery per well, reduction of well costs, early gas monetization and setting a clear Urban Plan early on during the appraisal stage.The presence of infrastructure, notably the nearby Yibal gas processing plant, and the proven presence of sweet spots make this cluster a prime candidate to provide the second wave of production following conventional reservoirs and a possible working model for future tight and unconventional gas developments.This presentation summarises results to-date, highlights the key elements of the roadmap towards success and key enablers towards an economically commercial viable development.