The first Borehole to Surface Electromagnetic (BSEM) pilot field survey in the Kingdom of Saudi Arabia (KSA) was successfully executed to identify oil and water bearing reservoir layers in a carbonate oilfield water injection zone. Maximizing recovery factor by means of detailed mapping of hydrocarbon accumulations in the reservoirs is a key requirement for oil producing companies. This mapping is done routinely by accurate measurements of fluid distribution at the wells' locations, but a knowledge gap exists in the inter-well volumes, where typically only density-based measurements are available (seismic and gravity). Such technologies are not always effective to discriminate and quantify the fluids in the porous space (especially when difference in fluid densities is small, such as oil and water). On the contrary, when high electrical resistivity contrasts exist between hydrocarbons and water, electromagnetic (EM) based technologies have the potential to map the distribution of the fluids and monitor their movement during the life of the field, hundreds of meters or kilometers away from the wellbores. The objective of a BSEM survey is to obtain fluid sensitive resistivity and induced polarization maps. These are based on an acquisition grid at the surface, a few kilometers around the EM transmitting well, which reveal oil and water bearing zones in the investigated reservoir layers. In this pilot field test, BSEM showed the potential to map water-front movements in an area of about 4km from the single well surveyed, evaluate the sweep efficiency, identify bypassed/ lagged oil zones, and eventually monitor the fluid displacements, if surveys are repeated over time. The data quality of the recorded signals is highly satisfactory. Fluid distribution maps obtained with BSEM are coherent with production data measured at the wells' locations, filling the knowledge gap of the interwells area.Three key R&D objectives for this BSEM pilot are achieved. Firstly, the capability to record at the surface EM signals generated in the reservoir, secondly, the capability of BSEM to discriminate between oil and water saturated reservoir zones, and finally obtain resistivity maps and a fluid distribution estimate plausible and coherent with the information obtained from well logs, crosswell EM, production data and reservoir models. In addition to reservoir monitoring, BSEM can be very useful in non-diagnosed areas like exploration fields for hydrocarbon exploitations.

Horizontal wells with extended reach drilled in Ghawar field awarded significant improvements, maximizing hydrocarbon production and attained ultimate recoveries. Over the life of those wells, intervention work is necessary to maintain hydrocarbon production by conducting remedial action, such as acid stimulation or water shut off. Necessary data for decision making can be obtained through running surveillance tools, which has proved to be a challenge, considering that these sensors will have to be deployed to total depth (TD). Many well intervention methods have been developed over time to overcome these challenges, such as coiled tubing (CT) and several types of wireline tractors. Wireline tractor technology has evolved to reduce time, cost and improve data quality and increase wellbore coverage. The use of a wireline tractor imposes fewer personnel on the job, much less equipment and less lifting of heavy loads resulting in a smaller footprint impacting the environment. In addition, the fast rig up of the wireline tractor and the running in hole (RIH) and pulling out of hole (POOH) speeds the highly deviated section, and cuts down on operating time. This paper will demonstrate horizontal logging experience gained from trial testing a new deployment solution for the production logging tool (PLT). A new generation of wireline tractors was utilized successfully to deploy the PLT for the first time in the Saudi Arabian field and showed exceptional performance. The tractor proved its capability to overcome different challenging wellbore conditions, such as rugosity, washouts, and high dogleg severity (DLS). Moreover, the tractor was able to efficiently pass through very short sections with large changes in the inclination and azimuth, This paper also covers the whole cycle of candidate selection, job design, execution challenges, post job evaluation, lessons learned and experience gained to optimize similar future jobs.

In today's drive to improve well production and performance, more innovative methods are continually being implemented to enhance well productivity and reservoir management. By increasing reservoir contact and applying fit for purpose technologies, increased production can be attained at lower drawdown. This can be accomplished by the effective implementation of multilaterals wells. In multilateral wells equipped with active downhole control valves and downhole measurement-devices, monitoring and managing the production from each lateral is achievable. These capabilities will enhance well performance and allow better sweep; hence better recovery. This paper describes the design, completion, commissioning, and operational experience of the world's first well equipped with intelligent completion combined with fiber-optic monitoring capabilities. Well-A is a trilateral MRC well with more than 5 km of total reservoir contact. The monitoring system for each lateral includes an optical flowmeter and pressure and temperature gauge. The readings of the flowmeter were compared to the readings against the conventional testing facilities. Production tests were conducted with various combinations of downhole valve positions for each of the three laterals to determine the optimum combination. The pressure and temperature gauges yielded excellent measurements as they were verified against conventional pressure and temperature measurements. The downhole flow rate measurements were assessed against conventional rate measurements and demonstrated acceptable results across most downhole valve positions. A comprehensive review was conducted on the optical flow meter capabilities to provide better understanding; hence, facilitate further enhancement to the technology and better production optimization capabilities. The review was utilized to develop a new system that provides better capabilities across all valves positions. Background The adoption rate of optical sensing technology for in-well permanent monitoring has accelerated dramatically since it was first introduced more than a decade ago. Today, most of the common electronic-based technology measurements for in-well permanent reservoir monitoring have a commercially available optical equivalent; such as pressure, temperature, seismic, and flowmeters. In fact, optical monitoring has exceeded the functionalities of conventional downhole measurement devices. The new fiber-optic devices provide various measurement capabilities such as Distributed Temperature Sensing (DTS), Array Temperature Sensing (ATS), and non-intrusive single and multiphase flowmeters.

As the world's demand for natural gas hits new records, technology developers and researchers work interactively to provide new technologies that support gas production and supply. Among these technologies come isolation plugs: mechanical and chemical. Chemical plugs have two main advantages over mechanical plugs. First, chemical plugs enable more flexible movement for Coiled Tubing (CT). Second, chemical plugs are easier to remove once unneeded using acid. Fluid systems used as diverters and temporary plugs in stimulation and work-over operations, are mostly polymer-based fluids that generate less damage to the formation and can hold higher differential pressures. The use of this technique has minimized the need for mechanical packers, bridge plugs and mechanical diversion techniques. One application for chemical plugs is selective zonal stimulation, where a coiled tubing and chemical plug are used in multi¬zone gas wells to selectively stimulate zones of interest. This paper outlines the first, in Saudi Arabia Gas Fields, successful deployment of a chemical plug— using CT — to stimulate the lower interval while isolating the upper producing interval. In addition, the plug's key characteristics, optimum rate and amount are addressed. Analysis of the post-treatment results, production rate and flowing wellhead pressure, demonstrated a very positive productivity.

In a strive to reduce the domestic reliance on oil, Saudi Arabia continues to sustain and increase it is production of naturel gas by drilling and stimulating new gas wells in Gahwar field. The newly drilled wells by default will not have the required permanent surface equipment to flow the free gas and condensate to the gas plant during the testing process of the productivity of the well. This testing process may extend for days, particularly when the well undergoes fracturing stimulations where hundreds of barrels of stimulation fluids are pumped into the formation in high pressures to create artificial fractures into the pay zone to enhance the well productivity. Such operations require extended flowback periods to clean up the well in order to reach the required production fluid criteria. This paper will focus on the first successful application of the spoolable reinforced thermoplastic pipe (RTP) in Saudi Arabia gas field. A 10,500 ft of 4" high pressure-high temperature RTP line was temporarily spooled and connected from a newly stimulated well to a flowline of a pre exiting well which allowed to flow back a significant amounts of free gas and condensate to the gas plant. Testing separators were utilized during the flowback operation to insure a low water cut production to the gas plant. Challenges like large operating area, high H2s content, nearby oil and gas wells, the installation and dismantle process of the RTP line after completing the operation were faced and resolved during the implementation of this technology. Utilizing RTP during the testing period of the well saved the environment from unnecessary emissions of heat-trapping gases and is proven to be economically beneficial. However, it may not be possible to implement it in every well due to safety and geographical reasons.