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Vol. 8, No.4 |
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Tech Transfer Track
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Geological Analogs—Benefits and ShortcomingsIn late 2001, Quittut Consulting LLC conducted industry interviews to gather insights about industry use of geological analogs. Six majors, nine international independents, two national oil companies, four U.S. independents and two independent geologists were interviewed. Titles and job responsibilities for those interviewed spanned executives, managers and professional staff. Most of those interviewed had more than 20 years experience. The study had two goals: (1) assess the real-world use and methodology of geological analogs in general and digital analogs in particular and (2) determine the merits and effectiveness of the analog approach in exploration and field development. Here is what was discovered. Nearly all E&P companies use analogs extensively, however best practices have not really been codified. Although widely used in peer review meetings, analogs are seldom part of look-back or post-mortem evaluations, a critical shortcoming. Widely used by geologists in the past, reservoir engineers and petrophysicists are increasingly using the analog approach to fill in data gaps. Management and professional staff felt that using geological analogs:
They observed that best practices for using geological analogs need to be established, documented and published. They stressed the need for a consortium to study methodology for integrating seismic analog information with outcrop and subsurface geological data and engineering data. They also noted that geoscience professionals need to be reminded that decisions based on close-ology may not be sufficient. Respondents favored digital analog systems because of: (1) quick and efficient information finding, (2) digital data are easier to manipulate and analyze, and (3) it is much easier to make global comparisons, leading to higher quality decisions. With digital analog databases, interviewees noted that the quality of analog data was more important than the quantity—i.e., a thoroughly studied analog beats numerous case studies that have lots of empty data points. Excerpted from "Geological Analogs Usage Rates High in Global Survey," by S. Qing Sun and J.C. Wan, Oil & Gas Journal, Nov. 11, 2002, p. 49-50. |
Oil & Gas Measurements—Tips To Improve Your ProfitsThe Oklahoma Marginal Well Commission, in conjunction with PTTC's South Midcontinent Region, recently presented a series of workshops in Oklahoma addressing problems associated with the marketing of crude oil and natural gas. The following tips and processes learned should be applicable for many oil and gas producers. The temperature factor has the most impact in determining the volume/value of crude oil when measured in the stock tank. When thinking of how to orient the stock tank to benefit from temperature correction, think NEWS (North, East, West and South). The north side stays the coolest year-round, thus samples taken from the north side are coolest, then followed by east and west. The south side will be the hottest location, resulting in the most unfavorable temperature correction factor for the producer. Another lesson learned is to know the solvent used by the crude oil purchaser during the testing of the crude. The American Petroleum Institute (API) recognizes only five solvents acceptable for this purpose: Stoddard solvent, Toluene, Xylene, Kerosene and white gasoline. The most common solvent used to dilute the test sample of crude oil is unleaded gasoline, which can contain up to 0.3% water in itself. For those sites that are transported by truck and the truck driver tests the crude oil before hauling, the crude is typically diluted with diesel as a solvent. Diesel most definitely contains some volume of water. Your "grind out" or "shake out" of the crude sample can read as high as 3/10's water and it actually came from the diesel used to dilute the sample. When measuring natural gas through a meter run, the API specifications require the interior surface of the meter run tube be very smooth, basically as smooth as the inside of a shotgun barrel. If not, the roughness causes turbulence and causes the meter to read less than actual volume. Another tip is not to "pinch" or dampen the valves under the meter to reduce red pen sweep. Dampening the meter causes slow pen response and causes the meter to read less than actual flow through the meter run. Courtesy of Sam Farris (sfarris@oklaosf.state.ok.us), Oklahoma Marginal Well Commission. |
World Oil's "Next Generation" AwardsWorld Oil's "Next Generation" awards highlight the creative thinking, strong leadership and technological innovations that drive the E&P industry. The awards cover all facets of the exploration, development and production industry. A 17-member Advisory Board, most well recognized in industry and representing different sectors of the industry, provided guidance in identifying and objectively assessing the winners.
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