Accretion is a common phenomenon that affects drilling operations in the Orinoco Heavy Oil Belt. The main reservoir, where most horizontal sections are drilled, is the Oficina Formation. Accretion negatively impairs operational efficiency, thus generating stuck pipe incidents, problems while tripping due to high torque and drag values related to friction factors, and the unrecommended backreaming operations. In addition, accretion causes excessive fluid surface losses linked to plugged shakers screens. This document shows the laboratory tests and successful field results obtained from the combination of specialized surfactant and lubricant agents working in synergy to reduce the accretion effect. The laboratory test demonstrated the synergy between the lubricant and surfactant in different tests, such as lubricity, accretion, and permeability damage testing. In the field, positive results were achieved in nine horizontal wells, thus increasing operative efficiency by reducing stuck pipe incidents, backreaming operations, and unplanned trips. This impact over flat times was also accompanied by a fluid waste reduction that improved the shakers’ screen usage and reduced the amount of oil coating the cuttings, which facilitated the treatment process and minimized environmental impact.

Drilling an exploratory well in highly sensitive environments imposes a number of challenges for an Oil Company. One of these challenges is to provide Heli-portable logistic coordination to achieve a successful drilled well in the most cost/time effective manner keeping in mind that hundreds of people, equipment, supplies and fuel have to be transported to and from the rig in the safest way1. The solution implemented is based on the proven concept of integration of services. In this case, the methodology was adapted to the condition of the remote location with heli-portable logistics, in which the key factors are Logistics, managed by the Operator and Service Companies, shared Drilling Engineering, Risk Management, identification and selection of new technologies and pre-defined communication and responsibilities flowchart among Operator, Service Companies and Rig Contractor. The initial time planned for the exploratory Oglan 2 Dir well was P-10: 32.7 days, P-50: 37.4 days and P-90: 49 days with an initial estimated NPT < 15%. The total duration of the well was 38.1 days, with an NPT of 15% due to operational difficulties encountered while acquiring downhole data and other operational events; however, 0% NPT was related to heli-portable logistics. Pre-established communication and responsibilities flowchart together with risk management allowed the achievement of goals and targets: coring 220 feet of Hollín Formation (main well target), acquire LWD on all the section and WL open hole logs in 81/2" section and, the most relevant goal, take fluid samples from Hollin and Napo Formations using a Saturn Tool. This methodology and concepts can be used as a guide for any heli-portable and/or remote operations with a pre- defined management and communication workflow among Operator, Service Companies and Rig Contractor reaching the main goal to meet AFE time and cost.

This paper describes a methodology that can be used to estimate the potential value of implementing digital and automation technologies in the well construction process in the context of a complex deepwater environment during the drilling conceptualization phase. This serves as a guideline for those interested in quantifying the value of applying digitization and automation processes, not only to make informed decisions related to investment in drillship or systems hardware and software but as well as performance improvement.

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