Every year, the complexity of horizontal wells grows, and matrix stimulation of these wells is key for maintaining production levels and improving the draw-down from producing formations. In the subject field, many wells are drilled as mega-reach with measured total depths up to 33,000 ft. The mega-reach represents a significant challenge for coiled tubing to reach the total depth (TD) and perform well interventions such as stimulation and logging. Coiled tubing (CT) may lock up before TD, and it can be challenging to understand the root cause. One difficulty is differentiating between lockups due to the well conditions and bottom-hole assembly (BHA) malfunctions. Electric submersible pump (ESP) completions contain bypass assemblies that impose an additional challenge introducing a restriction in tubing internal diameters. The restriction is less than 2.50" in the completion, increasing to 8-1/2" for the open hole, extending for at least 5,000 ft laterally in the producing formation. With the large variation in internal diameter (ID), the hydraulic tractor option is excluded from the mega-reach aid list, though it has proven reliable in extending the reach of CT for 6-1/8" openhole sizes in the same field. Therefore, the challenge here is to derive the maximum output possible from fluidic oscillation vibratory tools to achieve forces close enough to tractor forces and ultimately accomplishing the intervention objective. A combination of mechanical and chemical solutions was the designated approach to tackle the challenge. After reviewing all the possible solutions, tractors were excluded due to the extreme expansion ratio needed resulting in lower pulling forces. A fluidic oscillation tool inducing axial vibration of an absolute magnitude exceeding 1,600 lbf was yard tested and deployed as a solution in combination with a selection of friction and drag reducers. This paper will illustrate the reach challenges, analysis performed, and show how we could utilize the latest developments in fluidic oscillation vibratory tools. It will also include downhole real-time data acquisition assisting the understanding of lockup occurrence, as well as quantifying the improvements in the pre-job tubing force model simulation.

Increased concerns from well testing activities about the environmental impact have left several oil industry challenges. Some of these challenges include handling well effluents from flow back operations with sour crude; the challenges can be more severe to contend with H 2 S safety, pollution and spill risk. Limited deck space in offshore environments often restricts the footprint of flow back equipment. An optimized solution to cater specifically for offshore operations requires careful design to ensure a safe yet functional flow back system. The pollution risk from fall out could have serious consequences to the marine life and habitat. Given that offshore operations typically cost an order of magnitude in excess of land based operations, weather uncertainties could typically result in cost overruns, increasing total job costs.The scope of the paper is to examine the evolution of well deliverability testing -from conventional flaring practices to contemporary smokeless and zero flaring operations in a giant carbonate oil field in Saudi Arabia, surrounded by a world class environmentally protected marine and coastal ecosystem. The examination of 100 well testing candidates, with 39 of those using the zero flaring approach, allows a demonstration of the clear cost, technical and economic benefits over traditional flaring techniques.Before the production facilities and flow lines were operational, the previous clean up method required flaring of oil and gas. Although best practices were applied, an environmental and technical cost accompanied the approach. With the completion of the flow lines and production facilities, the application of the zero flaring option became possible. The possibility to conduct zero flaring provides several attractive benefits, with at least the equivalent of 4,000 barrels of oil not flared, pollution avoidance, 50% time saving and over 50% reduction in total job costs for the field development.

Completion of the Manifa field development mega-project marked the world's largest hydrocarbon production increment in a single phase. Just as significant as its considerably large production scale, the project involved several green initiatives, including broad-spectrum environment conservation and protection, air pollution controls, and coastal/marine protection. Manifa's coastal and ecologically sensitive location is a source of livelihood for local farmers and contains habitat for fish, shrimp, coral reefs, and endangered species. Consequent upon the richness of species in the zone, the field warranted a development solution that was a balance between environmental stewardship and operational excellence. During Manifa's field development, a critically important environmental strategy was also developed for the construction of the causeway, central processing facility, gas and oil separation, water injection, and cogeneration plants, and 15 offshore platforms for oil production and water injection, with associated subsea pipelines and power communication cables. An environmental impact assessment (EIA) was completed and a continuous environmental monitoring program (EMP) was implemented during dredging and disposal of dredged materials, prior to and during the construction location of 27 man-made islands to achieve the EIA's mitigation criteria and guidelines. Four (4) studies were also commissioned by the King Fahad University of Petroleum and Minerals (KFUPM) in collaboration with the Spanish research institute AZTI-Technalia. The successful grassroots development of Manifa, without sacrificing a responsibility to protect the environment, is a testimony to the careful integration of interdisciplinary approaches from project onception to completion; and from exploration to delivery of hydrocarbons to end users. Innovative solutions led to contractor partnering, a strong health, safety and environment (HSE) culture and an exemplary environmental awareness and conservation approach, which resulted in a successful project with a positive influence on Saudi Arabia, the region and other parts of the world.

Discrete technology solutions, such as real time data acquisition, distributed temperature sensing, etc., applied on a selectedwell basis, seem to serve field development engineers well sometimes. For engineers to continually improve field-wide operations and attain the cost and production advantages necessary to stay competitive in an industry shifting to cost-effective applications, integrating workflows is a strategic imperative. Engineers will need to concentrate and excel not just on specific technologies, but on holistic rigless operations success driven by more attention to integration than individual technology solutions. The challenge facing asset teams remains how to execute comprehensive plans to make significantly higher returns from capital technology spending in the field. The scope of this paper is to present how engineers have adopted technology integration and alignment of CT reach and stimulation technology solutions for the specific situation of successfully developing and managing major oil carbonate field in readiness for a major production milestone. The approach presented entails an all-inclusive project-based method that involves performance reviews, elimination or reduction of idle times through close monitoring of incremental project stages, optimizing operational efficiency through increasing the speed of material delivery to the well sites, and improvement of logistics of people and equipment. The approach involves unifying role-based, process-based, and production workflows throughout the operation and building on a learning curve with each successive rigless operation. From the safe job execution of many rigless activities, a model or scorecard is available to control important variables, assess the effectiveness of specific technologies, and provide support for leading or lagging indicators. Consequent upon routine and seamless inclusion of technology-based exercises at a project level, rigless activities have been completed over 60% faster than when the campaigns started nearly five years ago. Monetizing this value of technology integration in auditable and quantifiable terms translate to significant gains over the course of the rigless campaign. Through integration, engineers can implement effective programs for improvement in service levels and improve operations. Eventually these gains translate to fewer obstacles to project delivery.