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Parker, Martyn (Pruitt Tool & Supply Co.) | Seale, Marvin (Red Willow Production Company) | Nauduri, Sagar (Pruitt Tool & Supply Co.) | Abbey, James (Red Willow Production Company) | Seidel, Frank (Seidel Technologies, LLC) | Okeke, Ernest (Pruitt Tool & Supply Co.)
Horizontal drilling in the Fruitland Formation, a Coalbed Methane (CBM) play located in the San Juan Basin (SJB), found across the states of Colorado and New Mexico can present a number of drilling and production challenges. Examples of these challenges include wellbore instability, severe fluid losses, high mud costs, formation damage, and post-well production issues.
Clear fluid brine systems such as Calcium Chloride (CaCl2) and Calcium Bromide (CaBr2) are usually preferred because of their compatibility with coals and their ability to minimize formation damage. However, these brines can instigate fluid losses, cause fluid handling issues, and create long-term production challenges. Coal instability in the horizontal play has historically led to events such as wellbore collapse, stuck pipe, lost Bottomhole Assemblies (BHAs), and challenges such as getting the pipe out of the hole at Total Depth (TD) and subsequently running completions. Ultimately, these problems led to sidetracks, incurring additional costs, time, and resources.
In May 2019, the Constant Bottomhole Pressure (CBHP) technique of Managed Pressure Drilling (MPD) was introduced to mitigate these challenges. Two wells with eight laterals and combined horizontal footage of ±46,000 ft were drilled using CBHP, maintaining 11.4 ±0.1 pound per gallon (ppg) Equivalent Circulating Density (ECD) and Equivalent Static Density (ESD) in the lateral at ±2800 ft True Vertical Depth (TVD). With a focus on safety and training, the mud weight was staged down from 10.8 ppg on the first lateral to 9.8 ppg on the second. The final six laterals were drilled with 8.6 ±0.2 ppg produced water. This paper will detail the planning, training and staged implementation of CBHP MPD with produced water. It will briefly discuss improvement in wellbore stability, cost reduction for drilling laterals, and enhanced production after switching to produced water.
The Wisting Field is located offshore in the Barents Sea north of Norway. The field development requires drilling and completion of horizontal wells in a narrow pressure window, which is challenging for conventional technology. The Reelwell Drilling Method (RDM) provides a solution for managed pressure drilling (MPD) to mitigate these challenges. Based on the use of dual-channel drillpipe, RDM enables the pressure gradient in the openhole section to be held constant and nearly independent of the drilling fluid flow rate. RDM provides low-energy drilling, i.e., efficient drilling and hole cleaning when using low flow and low-drillstring rotation speed. This allows drilling of horizontal sections within a small pressure window and limits drillstring fatigue in high-dogleg applications.
In order to start qualification of RDM for the Wisting Field, a horizontal trial well was drilled in fall 2018 at the Ullrigg Drilling and Well Test Centre, located at the NORCE Norwegian Research Centre in Stavanger, Norway. The goal for this trial well was to prove the dual-channel drillpipe capability to perform low-energy drilling, i.e., low-rotary speed, low flow, and stable downhole pressure gradient. The trial well had a challenging geometry with up to 14°/30-m build rate, as required for the field. The 9½-in. horizontal section was drilled in order to check the performance of the RDM and start the qualification of the RDM for the Wisting Field.
The trial well was drilled with a low-flow motor, i.e., with flow rates around 700 lpm. The string rotation speed was held lower than 5 rpm to limit drillstring fatigue in the high-dogleg section of the well. Efficient drilling and hole cleaning of the 9½-in. horizontal hole section was demonstrated. The results from the trial confirm the predicted performance for the RDM. The results indicate that RDM can keep well pressure gradient within the required window and mitigate the drilling challenges for the Wisting Field. The RDM architecture with return flow in the inner string represents a major advantage to avoid cuttings build up in the well, challenges with laminar return flow, formation wash-outs, mechanical down hole dynamics and ECD control by low energy drilling.
Decisions in E&P ventures are affected by Bias, Blindness, and Illusions (BBI) which permeate our analyses, interpretations and decisions. This one-day course examines the influence of these cognitive pitfalls and presents techniques that can be used to mitigate their impact. Bias refers to errors in thinking whereby interpretations and judgments are drawn in an illogical fashion. Blindness is the condition where we fail to see an unexpected event in plain sight. Illusions refer to misleading beliefs based on a false impression of reality. All three can lead to poor decisions regarding which work to undertake, what issues to focus on, and whether to forge ahead or walk away from a project. Strategic thinking and planning are key elements in an organisation’s journey to maximise value to shareholders, customers, and employees. Through this workshop, attendees will go through the different processes involved in strategic planning including the elements of organisational SWOT, business scenario and options development, elaboration of strategic options and communication to stakeholders. Examples are provided including corporate, business unit and department case studies. This seminar will teach participants how to identify, evaluate, and quantify risk and uncertainty in everyday oil and gas economic situations. It reviews the development of pragmatic tools, methods, and understandings for professionals that are applicable to companies of all sizes. The seminar also briefly reviews statistics, the relationship between risk and return, and hedging and future markets.
Learn more about training courses being offered. Learn more about training courses being offered. This course covers the fundamental principles concerning how hydraulic fracturing treatments can be used to stimulate oil and gas wells. It includes discussions on how to select wells for stimulation, what controls fracture propagation, fracture width, etc., how to develop data sets, and how to calculate fracture dimensions. The course also covers information concerning fracturing fluids, propping agents, and how to design and pump successful fracturing treatments. Learn more about training courses being offered. Current and future SPE Section and Student Chapter leaders are invited to engage and share.
Challenges In Drilling and Completion Of Extended Reach Drilling Wells with Landing Point Departure more than 10,000ft in Light/ Slim Casing Design. New Generation of HTHP Water Based Drilling Fluid Changing Conventional Drilling Fluids Solutions. Take Back Control of Your Capital Project with an EPC 4.0 Strategy Stratigraphical - Sedimentological Framework for the Thamama Group Development in the Western UAE Based on the Legacy Core Data: How the Key to the Future is Found in the Past. Ultra-deep Resistivity Technology as a Solution for Efficient Well Placement; Geosteering and Fluid Mapping to Reduce Reservoir Uncertainty and Eliminate Pilot Hole-first Time in Offshore Abu Dhabi, UAE. Performance Comparison of two different in-house built virtual metering systems for Production Back Allocation.
As Oil Companies Fade Away, Who Will Buy Their Wells? Shale producers proved they could pump out record volumes of oil by drilling horizontal wells and then fracturing them intensively. Now the industry needs to find buyers for many wells and acreage with hard-to-determine values. A company built with a plan to quickly profit from the shale boom began a slow decline when oil prices sank to $50/bbl. Others could be following it to bankruptcy court this year.
The companies will focus on research and development to reduce CO2 emissions and promote the circular economy. ADNOC’s drilling subsidiary has increased its rig fleet to 95 and plans to add “dozens” more by 2025. The upgrade project will increase the maturing field’s oil production to 485,000 B/D. This work describes a heuristic approach combining mathematical modeling and associated data-driven work flows for estimating reservoir-pressure surfaces through space and time using measured data. By racking up exploration agreements in the United Arab Emirates, Oman, and Bahrain, Eni took a big step forward in its pledge to tap into the Middle East’s vast swaths of highly prospective oil and gas acreage.