American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc. This paper was prepared for the 46th Annual Fall Meeting of the Society of Petroleum Engineers of AIME, to be held in New Orleans, La., Oct. 3–6, 1971. Permission to copy is restricted to an abstract of not more than 300 words. Illustrations may not be copied. The abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor of the appropriate journal provided agreement to give proper credit is made. Discussion of this paper is invited. Three copies of any discussion should be sent to the Society of Petroleum Engineers office. Such discussion may be presented at the above meeting and, with the paper, may be considered for publication in one of the two SPE magazines. Abstract Over 500 field applications have been made with a sand control process which achieves gravel packing and sand consolidation in essentially one treating step. It was designed to improve conventional gravel packing and yet offer advantages over sand control achieved by gravel packing followed by sand consolidation techniques. In a related application, successful repair of damaged areas in wire-wrapped screens or slotted liners in place has been accomplished with this method. This has eliminated the expense of pulling and repairing or replacing the screening device and then repacking. The application of the resin-sand pack method of sand control results in a strong, highly permeable filter around the wellbore. In addition, a portion of the formation sand may be consolidated with the treatment, resulting in an effective screen for preventing formation fines from entering the preventing formation fines from entering the pack sand and acting as a possible deterrent pack sand and acting as a possible deterrent to production declines which frequently follow gravel packs. The consolidated pack sand offers additional strength over gravel packs to withstand overburden and other stresses. This will tend to lessen damage to casing and cement jobs. Also, in conventional perforated casing completion treatments, perforated casing completion treatments, mechanical screening devices are generally not needed. The method described uses selected pack sand coated by a small quantity of furfuryl alcohol resin finely dispersed in a low viscosity oil. This provides for all the pack sand's being resin-coated. This method pack sand's being resin-coated. This method is generally more economical than gravel packs followed by consolidation techniques since the latter method normally requires more resin to coat all the gravel pack solids. Low pump rates may be used to minimize damage to the formation. The resin can be externally or internally catalyzed, a feature which allows flexibility of this method for use in perforated casing completions, around liners perforated casing completions, around liners in casing or open hole, or for repairing holes in old gravel screens or liners.

Summary Lime-based drilling fluids are commonly used in applications that require solids tolerance, low and stable rheological properties, resistance to contaminants, and inhibition to shales. The use of lime-based systems previously was restricted to environments in which temperatures were lower than 300°F because of excessive gelation of the mud at higher temperatures. Recent developments in drilling-fluid additives and solids-control equipment now permit the use of lime-based drilling fluids in high-temperature/high-pressure (HTHP) environments. Amoco Production Co. recently used a lime-based mud to drill a well offshore Texas in an HTHP environment. Predetermination of the drilling-fluid objectives contributed to the success of the operation. First, the drilling fluid had to satisfy U.S. Environmental Protection Agency (EPA) environmental discharge requirements. Second, stuck pipe and lost circulation, prevalent problems in offset wells, had to be minimized. Third, the fluid had to be stable to temperatures of 350°F and densities to 18.5 lbm/gal and to be resistant to CO2 and to saltwater flows. A high-temperature, lime-based system was developed and maintained to meet these drilling-fluid objectives. This paper describes the planning used to select the mud system, development of the formulation in the laboratory, laboratory testing to determine treatments during the course of the well, and the performance of the drilling fluid. This experience provided a unique approach to both the formulation and maintenance of a lime-based fluid used in hostile environments. Introduction Amoco Production Co., New Orleans Region, successfully used a lime-based drilling fluid in an HTHP environment. Mustang Island Well A-110, offshore Texas, was drilled to a total depth (TD) of 17,352 ft. The well was logged with a bottomhole temperature (BHT) of 338°F >350°F, interpreted by Horner plot) with an 18.5-lbm/gal mud density. Success of the operation was the result of careful well planning and prudent operational practices. Improvements made to a rather conventional lime-based drilling fluid to obtain a high-temperature/high-density (HTHD) formulation contributed to the well's success. In hostile drilling environments, many wellbore problems must be overcome to operate at maximum efficiency. In wells of this type, invert oil muds normally are used because they resist contaminants, provide wellbore stability, and are stable at high temperatures; however, oil muds pose environmental problems, and cuttings transportation and disposal can be expensive, especially offshore. If lost circulation occurs while an oil-based fluid is used, circulation is difficult to regain. Therefore, special consideration was given to use of a water-based fluid on this well. During well planning, offset well information was gathered to define operational problems and to determine pore pressures. Data from Mustang Island Well A-111 No. 3, drilled in 1986, were used to determine the casing program and pore pressures (Figs. 1 and 2) for the new well. Each hole section was then analyzed for problems common to that section of hole and recorded (Table 1). From these problems, a mud system was selected on the basis of the success of offset mud programs and overall economics. Four drilling-fluid objectives were then established for the well. The drilling fluid must (1) satisfy EPA environmental discharge requirements; (2) eliminate or minimize offset well problems; (3)remain stable at a temperature of 350°F with a density of 18.5 lbm/gal;and (4) be resistant to such contaminants as CO2and salt. Existing literature1–11 was researched to focus on the HTHP portion of the well. Research revealed that many of the typical dispersed fluids used in high-temperature environments contained a surfactant or a chromium compound to promote rheological stability.9,10 Such additives could prevent discharge of cuttings or mud into the Gulf of Mexico. The literature also showed that lime-based fluids could solidify as temperatures approached 300°F. This type of system was the most desirable because it directly addressed the problems listed in Table 1. The literature indicated that a high-temperature lime mud could be formulated with some new additives.1–4,6,7,11Laboratory testing was begun to formulate an HTHD lime-based fluid. The solids-control system on the rig was also evaluated to improve control of low-gravity solids. Such control was considered essential for any potential water-based drilling fluid to control rheological instability. Low-gravity solids or excessive additions of bentonite can lead to rheological instability, which, in turn, can cause lost circulation. The addition of two centrifuges was found to be cost-effective in controlling solids and was used during the drilling of the well (Table 2). From the literature and laboratory work, a lime-based fluid was developed that showed promise in addressing the drilling objectives while remaining stable under hostile environments (Tables 3 and 4). A plan was developed that required laboratory testing during the course of the well and direct communication between the Baroid Drilling Fluids and Amoco personnel to discuss real or potential problems. This paper discusses the reasons for the use of the lime-based flulid, the formulation of the drilling fluid, the testing to determine the proper product mix, and the results of these efforts. History of Lime-Based Muds Lime-based muds were used widely throughout the 1940's and 1950's. They were considered to be an inhibitive fluid with a tolerance to such common contaminants as salt, cement, and anhydrite. The rheologic properties of lime-based muds remain stable and low, even in a high-solids environment. They can be made with nearly any type of makeup water and easily maintained. As wells were drilled into deeper and hotter environments, however, severe gelation occurred; in the most severe cases, cementation of the mud occurred in the hole. Therefore, use of lime-based muds was restricted to environments with temperatures lower than 300°F and were discarded when a burned odor or severe gelation was observed during circulation after the mud was allowed to remain static in the hole. With more experience with lime-based muds, it was generally thought that a lower lime content could be used to increase the thermal stability of the mud at some expense toward inhibition. Thereafter, lime-based muds were classified as low-, medium-, or high-lime mud systems.

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