Beauheim 1987 - Waste Isolation Pilot Plant - U.S. Department of ...

More documents

Recommendations

Info

I I I I PRE-TEST STATIC PRESSURE i/- /FIRST BUILDUP PERIOD (FEU) ELAPSED TIME Figure 4-1. Components of a Drillstem Test and Slug Test the conclusion of the SFL, the shut-in tool is closed and the second buildup period (SBU) begins. Like the FBU, the SBU continues until the pressure- %.-time data cutve becomes asymptotic to the static formation pressure. As with the FBU, the data become more definitive the longer the SBU continues, and conditions improve for the next phase of testing. These four periods, the FFL, FEU, SFL, and SBU, generally constitute a complete DST cycle. On occasion, however, DSTs may include additional flow and buildup periods. DST flow rates are calculated rather than measured directly. The calculations are based on observed pressure changes over time caused by fluid filling the tubing, the known or estimated specific gravity of the fluid, and the size of the tubing. Because buildup-test analysis relies on the preceding flow rate@) being approximately constant, the actual rates during DST flow periods must be converted to one or more equivalent constant rates. This is done by dividing the total flow period into shorter time periods encompassing less flow-rate variation, and calculating the average rate over each time period. DST's were performed at well H-14 in the lower Dewey Lake Red Beds and in the Forty-niner, Magenta, and Culebra Members of the Rustler Formation; in the Culebra at well H-15; in the Fortyniner, Magenta, Culebra, and unnamed lower members of the Rustler at well H-16; in the Culebra at well H-17; in the Culebra at well H-18; and in the upper Castile Formation and Salado Formation at well WIPP-12. 4.2 Rising-Head Slug Tests Rising-head slug tests are most easily performed following DST's, while the DST tool is still in the hole. Following the second buildup of the DST, and while the shut-in tool is still closed, the fluid is swabbed out of the tubing. The shut-in tool is then opened to initiate the test. A rising-head slug test is performed in exactly the same manner as the DST flow periods, except that the test is not terminated after the flow rate changes by fifty percent (Figure 4-1). Ideally, the slug test should continue until the initial pressure differential has decreased by ninety percent or more. Practically, forty percent recovery generally provides 38
adequate data for analysis, particularly if log-log plotting techniques are used (Ramey et al., 1975). Rising-head slug tests can also be performed with a production-injection packer (PIP) set in a well on a tubing string. The water is swabbed from the tubing, and a small-diameter minipacker is quickly inserted into the tubing and inflated a short distance below the water level existing at that time. A transducer monitors the pressure below the minipacker. When the pressure stabilizes, the minipacker is deflated rapidly, stimulating flow from the formation into the relatively underpressurized tubing. The water-level or fluid-pressure rise in the tubing is monitored to provide the data needed to analyze the test. Rising-head slug tests were performed in the Culebra at wells H-1, H-14, H-15, H-16, H-17, H-18, and P-18; in the Magenta at well H-16; and in the Forty-niner clay(stone) at H-14 and H-16. 4.3 Falling-Head Slug Tests Falling-head slug tests are commonly performed after a well has been completed, when only one water-bearing unit is in communication with the wellbore. They are generally performed in lowproductivity wells that cannot sustain a pumping test. To prepare for a falling-head slug test, a packer is lowered into the well (or into tubing if a PIP is being used to isolate the test zone from other waterproducing zones) below the water surface and inflated. Additional water is then added to the well (or tubing) above the packer. After pressures above and below the packer have stabilized, the packer is deflated as rapidly as possible. This connects the overlying slug of water with the formation below, marking the beginning of the test. As with a risinghead slug test, a falling-head slug test should be continued until the pressure differential caused by the added slug of water dissipates to ten percent or less of its initial value. Frequently, almost complete dissipation of the pressure differential can be obtained. Falling-head slug tests were performed in the Culebra at wells H-1, H4c, H-12, WIPP-12, WIPP-18, WIPP-19, WIPP-21, WIPP-22, WIPPSO, P-15, P-17, ERDA-9, and Cabin Baby-1. 4.4 Pressure-Pulse Tests In water-bearing units whose transmissivities are so low (i.e., c 0.1 ftZ/day) that slug tests would take days to months to complete, pressure-pulse tests can be performed to determine the near-well hydraulic properties of the units. Pressure-pulse tests are most easily performed using a DST tool, and can take the form of either pulse-withdrawal or pulse-injection tests. For either type, the test interval is first shut-in and the pressure allowed to stabilize. The tubing string is either swabbed for a pulse-withdrawal test, or filled to the surface or otherwise pressurized for a pulse-injection test. The shut-in tool is then opened only long enough for the underpressure (pulsewithdrawal) or overpressure (pulse-injection) to be transmitted to the test zone, and then the shut-in tool is closed. In practical terms, it typically takes about one minute to open the tool, verify over several pressure readings that the pressure pulse has been transmitted, and close the tool. The dissipation of the resultant pressure differential between the test zone and the formation is then monitored for the actual test. As with a slug test, the pressure differential should be allowed to decrease by ninety percent or more. However, pressure-pulse tests proceed much more rapidly than slug tests, because equilibration is caused by compression/expansion of fluid rather than by filling/draining a volume of tubing, and hence attaining almost complete recovery is generally practical during a pressure-pulse test. Pressure-pulse tests were performed in the Fortyniner clay at well H-16, and in the lower Dewey Lake Red Beds at well H-14. 4.5 Pumping Tests When wells are sufficiently productive to sustain a constant pumping rate over a period of days to weeks, pumping tests are the preferred method of determining the hydraulic properties of water-bearing zones. Pumping tests are performed by lowering a pump into a well, isolating the interval to be tested with packers (if necessary), and pumping water from the formation at a nominally constant rate while monitoring the decline in water level or pressure in the well. Durations of pumping periods are highly variable, and are primarily a function of what volume 39
Page 1 and 2: SANDIA REPORT SAND87 -0039 UC - 70
Page 3 and 4: SAND87-0039 Unlimited Release Print
Page 5: a transmissivity of about 7 x 10-2
Page 8 and 9: 5 . TEST OBJECTIVES AND INTERPRETAT
Page 10 and 11: 3-18 3-19 3-20 3-21 3-22 3-23 3-24
Page 12 and 13: 5-35 H-l5/Culebra Drillstem and Slu
Page 14 and 15: 5-78 5-79 5-80 5-81 5-82 5-83 5-84
Page 16 and 17: A-2 A-3 A4 A-5 A-6 Single-Porosity
Page 18 and 19: 'H-6 o DOE-2 OHIPP-13 OAIPP 12 OH-1
Page 20 and 21: WlPP site. The aggregate thickness
Page 22 and 23: deep. The gamma-ray log used to gui
Page 24 and 25: 3347.11 ft \ - -12.25-inch HOLE -8.
Page 26 and 27: ~ 3409.6 n __ - - HOLOCENE DEPOSITS
Page 28 and 29: Ylf M (t -1wt 5 n nch REAMED BOREHO
Page 30 and 31: 3418.96 n 7.875-inch REAMED BOREHOL
Page 32 and 33: 2.375-inch TUBING 4.5-inch. 9.5 Ibl
Page 34 and 35: WELL CASING 2.375-inch TUBING TEST-
Page 36 and 37: 1.5-Inch GALVANIZED PIPE WELL CASIN
Page 40 and 41: (or areal extent) of the aquifer on
Page 42 and 43: :7001 J EQUILIBRATION / r.. .......
Page 44 and 45: Once straddle tests proved impossib
Page 46 and 47: 1300 c - J PRE-TEST PRESSURE IN TES
Page 48 and 49: - < a m L: * m 3 L a I Start Date:
Page 50 and 51: uildups were caused by the natural
Page 52 and 53: TABLE 5-1 EFFECTIVE DST FLOW RATES
Page 54 and 55: TABLE 5-2 SUMMARY OF NON-CULEBRA SI
Page 56 and 57: simulation shown, however, uses a t
Page 58 and 59: 1 .o 0.9 0.8 p' = 79.08 paig pi = 6
Page 60 and 61: ~ ~~ TABLE 5-3 SUMMARY OF CULEBRA S
Page 62 and 63: Two factors raised questions about
Page 64 and 65: 102 I I 1 1 1 W K 3 v) v) W K n v)
Page 66 and 67: 5.2.2.21 below) and DOE-2 (Beauheim
Page 68 and 69: ..A 225 - PRESSURE ABOVE TEST INTER
Page 70 and 71: 10' n ui K 3 v) v) W a n v) v) 100
Page 72 and 73: 10' MATCH PARAMETERS O n w a 3 v) v
Page 74 and 75: ..CI__._._..__....__.I 5.2.2.6 H-15
Page 76 and 77: 8.0 1 I I I MATCH PARAMETERS AP 1.0
Page 78 and 79: - 200 150 5 - EQUILIBRATION \Feu 'S
Page 80 and 81: 4.0 1 I 1 1 3.0 I n 2.0 1 .o 0.0 0.
Page 82 and 83: 1.0 0.9 0.8 0.7 0.6 0 0.5 0.4 0.3 0
Page 84 and 85: 3.0 .hl c El2 2.0 . v n I P 1 .o MA
Page 86 and 87: EI€3- 0.9 "O I OOATA - TYPE CURVE
Page 88 and 89:
4.0 I I I 3.0 MATCH PARAMETERS AP =
Page 90 and 91:
1 .o 0.9 0.8 0.7 1 MATCH PARAMETERS
Page 92 and 93:
1 .o 0.9 0.8 0.7 0.6 0 2 0.5 I 0.4
Page 94 and 95:
1.0, 0 I 0.9 0.8 0.7 0.6 0.5 0.4 MA
Page 96 and 97:
P-15 was bailed on four occasions i
Page 98 and 99:
1 .o 0.9 0.8 - p’ = 78.93 prig p,
Page 100 and 101:
Two type-curve matches are shown wi
Page 102 and 103:
0 5 I ELAPSED TIME. hours Figure 5-
Page 104 and 105:
10’ 1 I I I n a w 5 100 v) v) W a
Page 106 and 107:
MATCH PARAMETERS -ip 10 PSI 150 t 1
Page 108 and 109:
Considering that all other pumping
Page 110 and 111:
I ,EQUILIBRATION BUILDUP Elapsed Ti
Page 112 and 113:
0 9. w 10’ K =a 100 v) v) W a n v
Page 114 and 115:
10’ I I I a J P 100 v) v) W a n v
Page 116 and 117:
~ ~. SLUG t i /- i 3 Start Date 07
Page 118 and 119:
Figure 5-94 is a log-log plot of th
Page 120 and 121:
was followed by a 92-minute FBU. Th
Page 122 and 123:
10’ 1 1 1 1 a n w’ a = 100 v) v
Page 124 and 125:
and anhydrite, and were not conside
Page 126 and 127:
4.0 MATCH PARAMETERS .A. L. 21% 3.0
Page 128 and 129:
Estimates of the static formation p
Page 130 and 131:
10’ n w 2 100 v) v) w a P v) v) w
Page 132 and 133:
OWIPP-28. 70 OWIPP-27.650 OWIPP-30.
Page 134 and 135:
to Nash Draw where no halite is pre
Page 136 and 137:
observations regarding the potentia
Page 138 and 139:
7. SUMMARY AND CONCLUSIONS Single-w
Page 140 and 141:
REFERENCES Bachman, G.O. 1984. Regi
Page 142 and 143:
INTERA Technologies, Inc. 1986. WlP
Page 144 and 145:
Stensrud, W.A.; Bame, M.A.; Lantr,
Page 146 and 147:
(A-4)
Page 148 and 149:
distinct value of Coe2s. Pressure-d
Page 150 and 151:
The wellbore storage coefficient is
Page 152 and 153:
where: n = number of normal sets of
Page 154 and 155:
(A-21) and for spherical blocks the
Page 156 and 157:
where: tp* = Vfq, V = total flow pr
Page 158 and 159:
Figure A-5. Semilog Slug-Test Type
Page 160 and 161:
A.4 INTERPRET WELL-TEST INTERPRETAT
Page 162 and 163:
DISTRIBUTION: U. S. Department of E
Page 164 and 165:
INTERA Technologies, Inc. (9) 6580
Page 166 and 167:
WlPP Public Reading Room Carlsbad M
Page 168 and 169:
Nationale Genossenschaft fur die La
show all

Beauheim 1987 - Waste Isolation Pilot Plant - U.S. Department of ...

You also want an ePaper? Increase the reach of your titles

Delete template?

Save as template?