GATE has been awarded joint 3rd place the prestigious ZweigWhite Hot Firm Competition for the 2010 to 2013 period. Hot Firm is a competition that ranks the top 100 engineering, consulting and architecture companies in the US in terms of their growth over the previous three years. The rankings identify firms that have outperformed the economy and competitors to become leaders in their chosen fields. This is evaluated as a function of percentage and dollar growth to normalize across smaller and larger companies.
Grant Gibson, president of GATE, Inc., is the recipient of the 2013 Jerry Allen Courage in Leadership Award. Each year this Zweig White award goes to an individual in the architectural, engineering, and planning (A/E/P) or environmental industry who has uniquely demonstrated courage in their actions, which in turn has impacted their company and employees. The winner of this award demonstrates courage while overcoming obstacles on the path to company success. Jerry Allen, born in Texas in 1940, was known not only for his impactful contributions while being the CEO of Carter & Burgess, but also for his remarkable and inspiring leadership skills. While under Allen’s direction, Carter & Burgess grew from a firm of roughly 200 employees and $17 million in revenue during 1988, to 2,300 employees and $381 million in revenue during 2002.
Upon accepting the award, Grant Gibson said: “Most importantly, I want to thank the people that I work with every day. They’re the reason I get up to go to work. I enjoy working with them and seeing them succeed.”
GATE is a mid-size upstream oil and gas engineering consulting company based in Houston, Texas. GATE’s expertise is in areas of Materials & Corrosion, Commissioning & Initial Startup, Waterflood, Flow Assurance, Subsea Engineering, and Chemical Systems Engineering.
16360 Park Ten Place Suite 206
Houston, Texas 77084
Source: GATE, Inc.
2011 Abstract, Eric Caldwell, Karthik Annadorai, Grant Gibson, Lee Jordan
Subsea and topsides materials selection is becoming a vital part in the development and long term sustainability of deepwater oil and gas production facilities. Increasing challenges associated with capital and operating cost constraints, schedule compression, remote locations, and the need to deploy materials ever closer to their known limits makes fit for purpose materials selection a complex and difficult issue that crosses many different discipline boundaries. Materials selection is primarily governed by corrosion engineering principles and applied chemical inhibition practices, and then by project specifics. However, there are two different practices that are generally followed that dictate how materials are ultimately selected. The first is by a standard materials selection process using guidance such as that provided in NORSOK M-001, and the second is by using a more informal system with limited guidance that involves individually selecting materials for a specific project.
In actuality, the materials selection process is a combination of both. The selection process to identify which materials are considered appropriate is routine and straightforward and is dictated by various corrosion parameters and associated risks. Often this high-level assessment does not appropriately address project specifics, so causing the final material selections to be substantially different from those initially proposed.
One of the specific items that often drives this change in materials selection philosophy is the use of chemical inhibitors for corrosion inhibition and the perceived feasibility and level of risk associated with this. Use of a systems engineering approach to material selection can be used beneficially as a process that accelerates the determination and initial optimization of the materials, and the selection of chemicals and their injection locations, and associated monitoring methods and locations in a given topsides, subsea or water injection system design.
Source: SPE Annual Technical Conference and Exhibition, 30 October-2 November 2011, Denver, Colorado, USA
Copyright 2011. Society of Petroleum Engineers
2011 Abstract, Eric Caldwell, Grant Gibson, Lee Jordan
Martensitic stainless steels continue to be one of the most widely used corrosion resistant alloys in oil and gas developments. Determining if a martensitic stainless steel is acceptable in an unproven environment requires testing to confirm, but predicting the outcome of a given test environment is often initially based on personal experience rather than a qualitative and quantitative assessment. An empirical method for improving the predictability of NACE TM0177 Method A Tensile tests on modified 13Cr 110ksi grade martensitic stainless steels based on an H2S/Chloride/pH function has previously been developed based on published data in order to address this uncertainty. The environments considered by this function are only limited by the capabilities of the NACE TM0177 Method A test, and provide a method for rapidly estimating if a M13Cr 110ksi grade should pass or fail in multiple different environments. As a follow-on to the development of this empirical method, data points from new tests were used to check the general predictability of the H2S/Chloride/pH function. The general function was modified due to the addition of the new data, and subsequently checked again against a separate set of data. The nature and implications of these findings are discussed and conclusions drawn regarding the performance and value of the methodology for the evaluation of future materials applications.
Source: CORROSION 2011, March 13 - 17, 2011 , Houston, Texas
Copyright 2011. NACE International
2009 Abstract, Fady R. Chaban, SPE, GATE LLC; Mukul M. Sharma, SPE, and Ajay Suri, SPE, University of Texas at Austin; and Grant Gibson, SPE, GATE LLC
This paper presents an integrated and practical approach for implementation at the Front End Engineering Design (FEED) stage of a project to optimize the future field development strategy, injectors design, facilities planning, and to maximize the total value of the asset. The proposed method efficiently interconnect elements related to surface facilities, topsides process, subsea architecture, subsurface equipment, water quality, well completion, down-hole flow controls and target injection rates in a common context.
Source: SPE Annual Technical Conference and Exhibition, 4-7 October 2009, New Orleans, Louisiana
Copyright 2009. Society of Petrolem Engineers
In the last few years, Shell has implemented three deepwater waterflood systems. They are all on floating installations, employ relatively compact and light weight facility designs and are roughly the same capacity. While their overall designs are similar, important details of the designs are different, and the project management strategies were significantly different as well. The startup and initial run time experience of these waterfloods facilities differed greatly, ranging from significant downtime for the first project to nearly complete success for the last one. Shell is in the process of sanctioning a forth deepwater waterflood system that is larger and more complex than the previous three. Obviously, Shell has already learned a great deal about how to successfully implement a deepwater waterflood project. Before we develop the new project however, we are capturing our waterflood experience to date.
There is limited data on the performance of coatings, materials and cathodic protection systems installed subsea. Most systems remain submerged for their useful life and are often abandoned on the seabed. The recovery of the hardware provided an opportunity to autopsy the hardware for the purposes of validating cathodic protection designs and coating systems; specifically coating performance, anode consumption, and internal wall thickness allowances.
2005 Abstract, Lee C. Jordan, Justin P. Landry, Howard Duhon, and Grant T. Gibson, GATE LLC
This paper presents an overview of the impact of potential future reservoir souring and associated H2S production on the design decisions that must be made during the development of a deepwater production asset. The problem is inherently one of decision making under uncertainty, as determination of the likely magnitude of reservoir souring is a process requiring review of a large number of variables and the application of predictive techniques of limited accuracy. This paper reviews some of the practical uncertainties involved in predicting souring and identifies how these subsequently impact design and operability issues. By exhaustively identifying design objectives in the form of an objectives map it is possible to assess the impact of souring on all aspects of the design. Best practice approaches to risk management and mitigation are also presented in relation to the design of both water injection and production facilities.
Source: CORROSION 2005, April 3 - 7, 2005 , Houston, Tx
Copyright 2005. NACE International
2004 Abstract, Jonathan Marsh, Gibson Applied Technology; Grant T. Gibson and Michael Walsh, GATE LLC
This publication examines the issue of hydrogen embrittlement of CRA materials under the cathodic protection conditions often found in the up stream oil and gas industry. The environment in question is thus oxygenated seawater. The different possible mechanisms of hydrogen embrittlement for CRA materials under these conditions are discussed, as are the different factors affecting susceptibility and mitigation of susceptibility. The susceptibility of the different classes of materials is examined, and susceptible materials highlighted. The importance of undertaking a materials/CP review at different stages of a given project is proposed, and two case studies are described. Finally, a flow plan is put forward indicating the procedures that can be followed.
Source: CORROSION 2004, March 28 - April 1, 2004 , New Orleans, La
Copyright 2004. NACE International
2002 Abstract, Lianfang Li and William H. Hartt, Florida Atlantic University; Grant T. Gibson, GATE LLC; Steve L. Wolfson, Shell E&P
Umbilical functionality is critical to proper operation of subsea production systems, and for this reason it is important to properly select materials and corrosion protection options for this service. In this regard, specimens of a chromium-manganese-nickel duplex stainless steel (UNS S32001) in the normal, welded, and crevice conditions were exposed freely corroding and cathodically polarized for up to 413 days in natural sea water environments that were intended to simulate umbilical service. The results of these exposures are presented, and projections are made regarding appropriateness of this material for umbilical service.
Source: CORROSION 2002, April 7 - 11, 2002 , Denver, Co
Copyright 2002. NACE International