Petroleum System Analysis: Middle Magdalena Valley Basin, Colombia, South America

The purpose of this study is to create a petroleum system model and to assess whether or not the La Luna Formation has potential for unconventional exploration and production in the Middle Magdalena Valley Basin (MMVB), Colombia. Today, the Magdalena River valley is an intermontane valley located between the Central and Eastern Cordillera of Colombia. The underlying basin, however, represents a major regional sedimentary basin that received deposits from the Triassic through the Cenozoic. In recent years Colombia has been of great exploration interest because of its potentially vast hydrocarbon resources, existing petroleum infrastructure, and skilled workforce. Since the early 1900s when the MMVB began producing, it has led to discoveries of 1.9 billion barrels of oil (BBO) and 2.5 trillion cubic feet (Tcf) of gas (Willatt et al., 2012). Colombia is already the third largest producer of oil in South America, and there is good potential for additional unconventional exploration and production in the Cretaceous source rocks (Willatt et al., 2012). Garcia Gonzalez et al. (2009) estimate the potential remaining hydrocarbons in the La Luna Formation in the MMVB to be between 1.15 and 10.33 billion barrels of oil equivalent (BBOE; P90 and P10 respectively), with 2.02 BBOE cumulative production to date. Throughout the 1900s and early 2000s, Cenozoic continental and transitional clastic reservoirs were the primary exploration interest in the MMVB (Dickey, 1992). The Cretaceous source rocks, such as the La Luna Formation, are now the target for unconventional exploration and production. In the MMVB, the La Luna formation is characterized by relatively high total organic carbon (TOC) values, moderate maturity, and adequate thickness and depth (Veigal and Dzelalijal, 2014). The La Luna Formation is composed of Cenomanian-Santonian aged shales, marls, and limestones (Veigal and Dzelalijal, 2014). In addition to the in-situ hydrocarbons, the fractured limestones in the La Luna formation act as secondary reservoirs for light oil from other formations (Veigal and Dzelalijal, 2014). Thus the system can be considered more of a hybrid play, rather than a pure unconventional play. The Cretaceous source rocks of the MMVB exhibit excellent potential for unconventional exploration and production. Due to the complex structural nature of the MMVB, an understanding of the distribution of rocks and variations in rock qualities is essential for reducing risk in this play.

Relief Well Rehabilitation Options in Chief Joseph Dam Right Abutment Drainage Tunnel

This report summarizes the data, observations, methods, assumptions, and decisions for the design of the Relief Well Rehabilitation Project in the Right Abutment Drainage Tunnel at Chief Joseph Dam. Chief Joseph Dam (CJD) is a dam on the Columbia River and is owned and operated by the U.S. Army Corps of Engineers (USACE). It is the second only to Grand Coulee dam as the largest producer of hydropower in the United States. The right abutment drainage tunnel contains wooden stave relief wells. Water flows from these wells which reduces the hydrostatic pressure in the right abutment of the dam. The 22 wells in the floor of the tunnel are 60 years old and are in need of rehabilitation. The objective of this project is to control the groundwater gradient, prevent the movement of sediment, stop total screen collapse, and prevent initiation of backwards erosion and piping in the abutment. The rehabilitation solution is to install new stainless steel screens into the existing wells, backfill the annular space between the old wooden screen and the new stainless steel screens with a 3/8-inch pea gravel filter pack, and install a new top cap to hold the new screen in place. This report documents the data, observations, and methods used to complete the final design. During tunnel inspections USACE geologists observed dislodged end plugs and evidence of sediment movement out of the formation. The relief wells have historically high flows between 6,000 gallons per minute (gpm) to 9,000 gpm. New screens are designed based on as-built data and historic tunnel flow. The new screens are 8-in diameter, 100 slot (0.10-inch) screens. We found that screen diameter and slot size would provide adequate transmitting capacity for most of the relief wells. The filter pack gradation is based on descriptions from foundation construction reports. I found that 3/8-inch pea gravel is appropriate for the abutment material. During design, I also considered an option to install the screens into the relief wells without filter pack. I eliminated this option because it did not meet our rehabilitation objective to prevent total failure of the wooden screens.