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David Price
3821d810 1 parent fffb7e00

Load updated EPIM DPR2 test cases

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1 +<?xml version="1.0" encoding="UTF-8"?>
2 +<objects xmlns:xsi="http://www.w3.org/2001/XMLSchema-instance"
3 + xmlns="http://www.epim.no/schemas/mprml/1" version="1.0(MPRML)">
4 + <documentInfo>
5 + <DocumentName namingSystem="EC">TRYM February 2012</DocumentName>
6 + <DocumentAlias namingSystem="EC">TRYM Copex Report</DocumentAlias>
7 + <DocumentDate>2012-03-04T00:00:00.0Z</DocumentDate>
8 + <documentClass namingSystem="EC">Dong E&amp;P Norge AS</documentClass>
9 + <documentClass namingSystem="EC">DPR 2.0</documentClass>
10 + <documentClass namingSystem="ERH">dpr2</documentClass>
11 + <FileCreationInformation>
12 +
13 + <FileCreationDate>2012-03-14T00:00:00.0Z</FileCreationDate>
14 +
15 + <SoftwareName>Energy Components</SoftwareName>
16 + <FileCreator>Dong E&amp;P Norge AS</FileCreator>
17 + <Comment>NA</Comment>
18 + </FileCreationInformation>
19 + <Owner>Dong E&amp;P Norge AS</Owner>
20 + </documentInfo>
21 + <context xsi:type="obj_report">
22 + <kind>DPR 2.0</kind>
23 +
24 + <title>TRYM</title>
25 + <date>2012-02-28</date>
26 + <dateEnd>2012-02-28</dateEnd>
27 + <month>2012-02</month>
28 + <year>2012</year>
29 + <reportVersion>2.0</reportVersion>
30 + <reportStatus>final</reportStatus>
31 + <installation kind="field" namingSystem="NPD" uidRef="18081500">TRYM</installation>
32 + <operator>
33 + <name>Dong E&amp;P Norge AS</name>
34 + <role>Operating company</role>
35 + </operator>
36 + </context>
37 +
38 + <object xsi:type="obj_wellTest">
39 + <nameWell>3/7-A-1</nameWell>
40 + <name>Injection well test for well 3/7-A-1</name>
41 + <wellContext>
42 + <field namingSystem="NPD">TRYM</field>
43 + </wellContext>
44 +
45 + <testDate>2012-02-28T00:00:00.0Z</testDate>
46 + <previousTestDate>2012-02-10T00:00:00.0Z</previousTestDate>
47 + <lastValidTest>2012-02-23T00:00:00.0Z</lastValidTest>
48 + <testReason>other</testReason>
49 + <testType>combined test</testType>
50 + <standardTempPres>0 degC 1 atm</standardTempPres>
51 + <fluidLevelTest>
52 +
53 + <fluidLevel uom="m">135.03</fluidLevel>
54 + <baseUsableWater uom="m">135.03</baseUsableWater>
55 + <testedBy>Presumably, the desc</testedBy>
56 +
57 + </fluidLevelTest>
58 + </object>
59 + <object xsi:type="obj_wellTest">
60 + <nameWell>3/7-A-1</nameWell>
61 + <name>Injection well test for well 3/7-A-1</name>
62 + <wellContext>
63 + <field namingSystem="NPD">TRYM</field>
64 + </wellContext>
65 + <testDate>2012-02-28T00:00:00.0Z</testDate>
66 + <previousTestDate>2012-02-15T00:00:00.0Z</previousTestDate>
67 + <lastValidTest>2012-02-21T00:00:00.0Z</lastValidTest>
68 + <testReason>revision</testReason>
69 + <testType>combined test</testType>
70 + <injectionTest>
71 + <testDuration uom="h">6</testDuration>
72 + <testInterval>
73 + <mdTop uom="m">2697.65</mdTop>
74 + <mdBase uom="m">2767.45</mdBase>
75 + <wellbore>3/7-A-1</wellbore>
76 + <testedFormation>Brent</testedFormation>
77 + <valvePosition uom="ft/m">2750.15</valvePosition>
78 + </testInterval>
79 + <InjectedFluid>gas</InjectedFluid>
80 + <wellTestCumulative>
81 + <cumulativeOil uom="m3">3727.78</cumulativeOil>
82 + <cumulativeGas uom="m3">46490.79</cumulativeGas>
83 + <cumulativeWater uom="m3">2561.8</cumulativeWater>
84 + </wellTestCumulative>
85 + <chokeOrificeSize uom="in/64">78.69</chokeOrificeSize>
86 + <minimumAnnularPressure uom="bar">166.33</minimumAnnularPressure>
87 + <maximumAnnularPressure uom="bar">225.55</maximumAnnularPressure>
88 + <wellheadFlowingPressure uom="bar">74.44</wellheadFlowingPressure>
89 + <wellheadMaximumPressure uom="bar">98.51</wellheadMaximumPressure>
90 + <injectionTestResults>
91 + <oilVolume>
92 + <volumeStdTempPres uom="m3">3725.2</volumeStdTempPres>
93 + <densityStdTempPres uom="kg/m3">785.74</densityStdTempPres>
94 + </oilVolume>
95 + <oilRate>
96 + <fluidRateStdTempPres uom="m3/h">568.89</fluidRateStdTempPres>
97 + </oilRate>
98 + <gasVolume>
99 + <volumeStdTempPres uom="m3">6319.14</volumeStdTempPres>
100 + <densityStdTempPres uom="kg/m3">1.22</densityStdTempPres>
101 + </gasVolume>
102 + <gasRate>
103 + <fluidRateStdTempPres uom="m3/h">3550.3</fluidRateStdTempPres>
104 + </gasRate>
105 + <waterVolume>
106 + <volumeStdTempPres uom="m3">114.5</volumeStdTempPres>
107 + </waterVolume>
108 + <waterRate>
109 + <fluidRateStdTempPres uom="m3/h">123.22</fluidRateStdTempPres>
110 + </waterRate>
111 + </injectionTestResults>
112 + </injectionTest>
113 + </object>
114 + <object xsi:type="obj_wellTest">
115 + <nameWell>3/7-A-1</nameWell>
116 + <name>Production well test for well 3/7-A-1</name>
117 + <wellContext>
118 + <field namingSystem="NPD">TRYM</field>
119 + </wellContext>
120 + <testDate>2012-02-28T00:00:00.0Z</testDate>
121 + <previousTestDate>2012-02-10T00:00:00.0Z</previousTestDate>
122 + <lastValidTest>2012-02-23T00:00:00.0Z</lastValidTest>
123 + <testReason>initial</testReason>
124 + <testType>pressure buildup</testType>
125 + <productionTest>
126 + <testDuration uom="h">5</testDuration>
127 + <bottomholeData>
128 + <bottomholePres uom="bar">129.95</bottomholePres>
129 + <bottomholeTemp uom="degC">107.41</bottomholeTemp>
130 + </bottomholeData>
131 + <separatorData>
132 + <separatorPressure uom="bar">71.29</separatorPressure>
133 + <separatorTemperature uom="degC">54.09</separatorTemperature>
134 + </separatorData>
135 + <operatingMethod>flowing</operatingMethod>
136 + <productionTestResults>
137 + <oilVolume>
138 + <volumeStdTempPres uom="m3">1973.99</volumeStdTempPres>
139 + <volume uom="m3">1993.0</volume>
140 + <densityStdTempPres uom="kg/m3">745.3</densityStdTempPres>
141 + </oilVolume>
142 + <oilRate>
143 + <fluidRate uom="m3/h">553.13</fluidRate>
144 + <fluidRateStdTempPres uom="m3/h">629.01</fluidRateStdTempPres>
145 + </oilRate>
146 + <gasVolume>
147 + <volumeStdTempPres uom="m3">2038.86</volumeStdTempPres>
148 + <volume uom="m3">2037.09</volume>
149 + <densityStdTempPres uom="kg/m3">1.24</densityStdTempPres>
150 + </gasVolume>
151 + <gasRate>
152 + <fluidRate uom="m3/h">2329.36</fluidRate>
153 + <fluidRateStdTempPres uom="m3/h">2107.52</fluidRateStdTempPres>
154 + </gasRate>
155 + <waterVolume>
156 + <volumeStdTempPres uom="m3">2223.27</volumeStdTempPres>
157 + <volume uom="m3">1941.59</volume>
158 + </waterVolume>
159 + <waterRate>
160 + <fluidRate uom="m3/h">2301.54</fluidRate>
161 + <fluidRateStdTempPres uom="m3/h">2181.24</fluidRateStdTempPres>
162 + </waterRate>
163 + <gasOilRatio uom="%">57.9</gasOilRatio>
164 + <basicSedimentAndWater uom="%">2.78</basicSedimentAndWater>
165 + <oilPotential uom="1000m3/d">170.91</oilPotential>
166 + <gasPotential uom="1000m3/d">186.52</gasPotential>
167 + <sandVolume uom="m3">1.23</sandVolume>
168 + </productionTestResults>
169 + </productionTest>
170 + </object>
171 +</objects>
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