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A REVIEW of DRILL-STEM TESTING TECHNIQUES and ANALYSIS

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A REVIEW of DRILL-STEM TESTING TECHNIQUES and ANALYSIS FEATURE ARTICLE A REVIEW of DRILL-STEM TESTING TECHNIQUES and ANALYSIS W. MARSHALL BLACK HUMBLE OIL & REFINING CO. JUNIOR MEMBER AIME HOUSTON, TEX. Downloaded from http://onepetro.org/JPT/article-pdf/8/06/21/2237729/spe-589-g.pdf by guest on 02 October 2021 Abstract ether-cuts may be used to detect hy­ tion evaluation. Presently, tests in­ drocarbon shows. side casing are about 91 per cent The present techniques of using mechanically successful as compared the drill-stem test as a formation 2. Test possibly productive inter­ with 81 per cent 10 years ago, and evaluation tool are discussed. The vals in open hole after drilling deep­ er or reaching total depth; normally, conventional open-hole, wall packer basic drill-stem test operation is di­ testing is mechanically successful vided for discussion into three phases: this method requires that a cement plug be set for each test, unless strad­ about 87 per cent of the time as planning the test, performing the test, compared with 72 per cent 10 years and interpretation, both qualitative dle packer testing is employed. Side­ ago. and quantitative. The use of small wall cores and logs are commonly bottom chokes and large top chokes used to detect the shows. The Drill-Stem Testing Tool is suggested in order to permit quan­ 3. Test possibly productive inter­ Modern drill-stem testing tools are titative interpretation for gas-oil ratio, vals through perforations after casing highly versatile and consequently are productivity, and permeability. The has been set; log and core data may complex. The various components importance of measuring chloride be used in selecting the intervals. may be assembled in innumerable content on a suite of samples taken Drill-stem testing is widely used to combinations, either to provide spe­ from a recovered column of salt wa­ confirm or prove the presence and! or cial information or to provide for ter is illustrated. the producibility of oil and gas that emergencies that may develop. The is detected by the other services. The following paragraphs briefly outline Introduction testing program in a well can follow the functions of the more common anyone of the methods of drill-stem tool components. A drill-stem test is a temporary testing outlined in the preceding sec­ The three basic mechanisms or completion of the well. Drill-stem tion; however, the method of testing components of a drill-stem test tool tests are usually made for one or cored shows as the prospective pays are as follows: (1) the tester valve, both of the following reasons: ( 1) are penetrated is probably most wide­ (2) the by-pass valve, and (3) the to determine the producible fluid ly used at present. Under this meth­ packer. These three component content of a formation, and (2) to od, a test will usually be made after mechanisms will be found in some determine the ability of a formation penetrating a few feet into the pros­ form in any good drill-stem test tool. to produce. pective zone, and if the results are The functions of each of the basic components in the assembly are as Drill-Stem Testing Methods favorable, subsequent tests may be made in search for fluid contacts. shown below. The drill-stem test, or temporary completion, . can be made either in Testing programs during the early FUNCTIONS OF BASIC COMPONENTS OF TOOL open hole or inside casing through phases of field development are as 1. The Tester or Retaining Valve o. To prevent drilling mud from entering empty perforations. A drill-stem testing pro­ important as the coring and logging drill pipe while funning in. programs for delineation of the res­ b. To aid in preventing drilling mud from enter­ gram can be planned for a well so ing drill pipe while pulling out and, conversely, that the tests will be made in accord­ ervoirs and for establishing or con­ to aid in retaining formation liquid recovery with~ firming the gas-oil and oil-water con­ in the drill pipe. ance with one of three general meth­ c. To open the tool, permitting passage of forma· tacts. tion fluids into the empty drill pipe after the ods: packer is set. 1. Test possibly productive inter­ 2. The By·Pass or Equalizing Valve Trends in Drill-Stem Testing o. To permit mud under hydrostatic pressure to vals in open hole as the zones are Since the early days about three­ flow downward throug h the packer mandrel at the conclusion of the test into the hole below the penetrated; normally, this method is fourths of all drill-stem tests have packer. This action equalizes the pressure above used in conjunction with coring and and below the packer, making it easier to pull been performed in open hole prior loose. to setting oil string casing. This pre­ b. To provide additional area through which the Original manuscript received in Petroleum drilling mud can pass around the packer while Branch office on Sept. 15. 1955. Revised man­ dominance of open-hole testing defi­ running in and pulling out of the hole. uscript received May 1'6. 1956. Paper pre­ nitely places drill-stem testing in Note: The new "hydraulic testers" ore unitized sented at Formation Evaluation Symposium. teater valves and by·pass valves; the respective Oct. 27-28. 1955. Houston. Teo<. the category of exploratory forma- functions of these are unchanged. SPE 589-G JUNE,1956 21 3. The Packer amount of hole to test; (3) packer a core hole, or hole of reduced diam­ o. To bridge the hole at Q point immediately above (and also below on straddle tests) the zon,e to size or sizes; (4) location of packer eter, is drilled ahead for exploratory be tested, thus permitting this zone to be relleve~ purposes. Successful use of conven­ of hydrostatic mud pressure when the tool IS seat; (5) top and bottom choke opened and isolating the zone from other forma­ sizes; (6) probable length of flowing tional double-end wall packers re­ tions. Important auxiliary components of and shut-in period and use of dual quires a very close fit to the hole the drill-stem test tool are as follows: shut-in periods; (7) type of pressure size. Because· of this, a reduction in the disk valve, the shut-in pressure gauges, manner of placement in the hole size or rathole for the last 300 valve or tool, the formation or bot­ tool, and optimum pressure capacity to 500 ft of hole, including the test tom choke, the anchor pipe, and the and clock speed; (8) use of, type, zone, permits greater packer clear­ pressure recorders. In addition to and location of circulating sub, safety ance while running in and out in these, a circulating valve, a safety joint, and jar; (9) use of water cush­ the full hole. Ratholing is largely joint, and sometimes a set of jars ion and amount; (10) method of confined to soft formation areas. may be included in the test tool or handling test production at the sur­ It has been found that the ratio in the drill pipe or tubing string. face; and (11) special packer ar­ of hole size to packer size largely rangements. governs the amount of packer com­ FUNCTIONS OF AUXILIARY COMPONENTS IN pression that will occur at pressure TYPICAL TEST TOOL STRING Amount of Hole to Test 1. The Disk Valve differentials up to 5,000 psi and that o. To aid in preventing drilling mud from enter­ In most instances, a more conclu­ ing the drill pipe while running in. leakage or rupture of the rubber b. To permit the packer to be set firmly and tester sive test can be obtained by testing element will occur if the ratio of valve opened before the tool is finally opened by the shortest section practical. In thin dropping a go-devil to rupture the disk valve (as hole size to packer size is such that used with certain tool assemblies). sands, where it is desired to locate complete mandrel travel is attained. Downloaded from http://onepetro.org/JPT/article-pdf/8/06/21/2237729/spe-589-g.pdf by guest on 02 October 2021 2. The Shut-In Pressure Valve or Tool o. To permit the test tool to be closed at the con­ the gas-oil and oil-water contacts, a A differential pressure of 5,000 psi clusion of the flow period with reduced likelihood test zone of 2 to 5 or 10 ft is often of unseating the packer or letting pressure equal­ will produce complete compression ize around the packer through the by-pass. used in open hole. Where producing when ratio of hole size to packer b. To aid in preventing drilling mud from enter­ ing the drill pipe while pulling out and, converse­ zones of greater thickness are en­ size approaches 1.25; 5,000 psi dif­ ly, to aid in retaining the formation liquids recov· countered, it may then be feasible to ered within the pipe. ferential pressure will cause about 3. The Formaton or Bottom Choke test more hole per test. This is par­ 50 per cent compression when ratio a. To restrict the volume of formation fluids that flow through the drill pipe to the surface. ticularly true in long limestone sec­ of hole size to packer size is about b. To hold some backpressure under the packer, tions where the location of the porous which reduces the hydrostatic load on the packer, 1.08 or 1.10. In the commonly and to reduce the amount of pressure drawdown in zones may not be known, and it is drilled hole sizes, the 1.08 ratio pro­ the formation.
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