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HomeMy WebLinkAboutAEO 003 1) 2) 3) 4) 5) 6) 7) 8) 9) 10) 11 ) 12) 13) ~~-f INDEX Aquifer Exemption No. 3 Lewis River Well D-l December 1, 1988 December 7, 1988 N/A December 14, 1988 January 13, 1989 January 13, 1989 January 13, 1989 January 20, 1989 March 28, 1989 April 24, 1989 April 26, 1989 May 2, 1989 ---------------- Unocal's Application ABO Lewis River D-l copy ofUnocal's AIO Support Documents AEO #3 Notice of Hearing, Affidavit of Publication Sign In Sheet Transcript Trustees for Alaska's Public Testimony Unocal's Addendum to request Ltr from US EP A re: Application Ltr from Trustees for Alaska re: for a rehearing Ltr from Governor's office, Division of Governmental Coordination certification of the ACMP AOGCC response to Trustees April 24, 1989 request Results of Test Drilling and Hydrogeology of Capps Coal Field Alaska Aquifer Exemption Order No. 3 - ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501-3912 Re: THE REQUEST OF UNION OIL) COMPANY OF CALIFORNIA ) FOR a Freshwater Aquifer) Exemption Order. ) Aquifer Exemption Order No. 3 Lewis River Well D-l Lewis River Gas Field March 30, 1989 IT APPEARING THAT: 1. By letter dated December 1, 1988, Union Oil Company of California (Unocal) submitted an application requesting the Alaska Oil and Gas Conservation Commission (the Commission) to issue an order exempting those portions of all freshwater aquifers occurring below the depth equivalent of 2300' in Lewis River Well D-1 and falling within an area circum- scribed by a one-quarter (~) mile radius around the well. 2. Notice of an opportunity for a public hearing on January 13, 1989 was published in the Anchorage Daily News on December 14, 1988. 3. By letter dated December 28, 1988, Trustees for Alaska and the Alaska Center for the Environment protested issuance of subject aquifer exemption and requested a hearing for Unocal's Freshwater Aquifer Exemption Order request. 4. On January 13, 1989, at 9:00 AM AST in the conference room of the Alaska Oil and Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, Alaska, a hearing was held on Unocal's application for an order exempting portions of freshwater aquifers below 2300 feet in the area of Lewis River Well D-1. 5. The hearing record remained open to provide for the filing of additional comments for the hearing record, with Trustees for Alaska agreeing to make filings on January 18 and 27, 1989; and Unocal agreeing to make a filing on January 20, 1989. Unocal and Trustees for Alaska made their filings as -scheduled. No public comments were filed. - ~ Aquifer Exemption Order No. 3 March 30, 1989 Page 2 6. The Commission has jurisdiction in this matter by authori- ties expressed in AS 31.05.030(h), 20 AAC 25.440, and 40 CFR 147, Subpart C - Alaska. 7. In accord with Section 13 of the January 29, 1986 Memorandum of Agreement between the U.S. Environmental Protection Agency, Region 10, (USEPA Region 10) and the Commission, a copy of Unocal's Freshwater Aquifer Exemption request was submitted to USEPA Region 10 on December 2, 1988. 8. The hearing record closed at 5:00 PM, January 30, 1989. A copy of the hearing record was promptly submitted by the Commission to USEPA Region 10. FINDINGS: 1. Trustees for Alaska raise the questions of: 1) whether Unocal has applied for a waste disposal permit or an Alaska Coastal Zone Management Program (ACMP) consistency determin- ation; 2) the Commission's authority to exempt aquifers outside the boundaries of existing oil and gas units; 3) whether the Commission's procedures for processing Unocal's application must conform with 40 CFR 124, Subpart A; 4) whether the Commission's procedure for issuing a public notice must conform with the public notice require- ment of 40 CFR 124; 5) the appropriateness of substituting an analytical well log analysis for a laboratory analysis of fluid samples to determine the total dissolved solids of formation fluids; 6) whether aquifers requested for exemp- tion are penetrated by a water well; and 7) need for a determination of consistency with the ACMP. 2. The Commission's authority to act in this matter is embodied in 40 CFR 147 Subpart C, the Alaska Oil and Gas Conservation Act (AS 31.05), and the Alaska Administrative Code (20 AAC 25.005 through 20 AAC 25.570). 3. The Commission's procedures in matters involving handling of the subject application and posting of public notice fully conforms to the Alaska Oil and Gas Conservation Act, AS 31.05; the Commission's regulations, 20 AAC 25; and 40 CFR 147 Subpart C (which is in consort with those sections of 40 CFR Part 124 that apply to state UIC program require- ments as set out by 40 CFR 145 Subpart B). 4. The analytical determination of the sodium chloride equiva- lent for total dissolved solids occurring in formation water from the wireline log measurement of osmotic electromotive forces generated in a wellbore has been an accepted industry , ",,-,/ -- Aquifer Exemption Order No.3 March 30, 1989 Page 3 practice for over 50 years. 20 AAC 25.252(c)(10) provides the authority for the Commission to accept analytical methods in lieu of a laboratory water analysis determination. 5. Investigation of freshwater resources in the general area of the Lewis River Gas Field indicate that all freshwater supply wells are 300 feet or less in depth. 6. The portions of freshwater aquifers occurring at depths of 2300 feet or more in Unocal's Lewis River Well D-1, and within an area circumscribed by a one-quarter (\) mile radius around Unocal's Lewis River Well D-1, do not serve as a source of drinking water and cannot be reasonably expected to supply a public water system. 7. Those portions of freshwater aquifers occurring at depths of 2300 feet or more in Unocal's Lewis River Well D-1 contain ground water with a total dissolved solids content in excess of 3000 mg/l and less than 10,000 mg/l. 8. Drill stem tests of formations below 2300 feet in Unocal's Lewis River well D-1 and of stratigraphically equivalent formations in other wells within the general area indicate the formations to be low in fluid productivity. 9. Water produced by Pretty Creek Unit #2 from an equivalent stratigraphic section exhibits TDS in excess of 5000 mg/l. 10. The freshwater supply wells in the general area exhibit formation productivity that is several fold the indicated productivity for aquifers below 2300' in Unocal's Lewis River Well D-l. 11. Based on wireline log interpretation, abundant freshwater aquifers occur from the land surface to a depth of 1000' in Unocal Lewis River Well D-l that appear to contain fresh- waters of less than 3000 mg/l. 12. Unocal has applied for an ACMP consistency determination for the activities it proposes to conduct at Lewis River well D-l. Pursuant to AS 46.03.100(d), Department of Environ- mental Conservation permits are not required for injection activities at Lewis River Well D-1. 13. By letter of March 28, 1989, the USEPA Region 10 approves the exemption of freshwater aquifers occurring below 2300' in Unocal's Lewis River Well D-1, Lewis River Gas Field. --- '-" Aquifer Exemption Order No. 3 March 30, 1989 Page 4 CONCLUSION: Freshwater aquifers occurring at depths of 2300' or more in Unocal's Lewis River Well D-1, and within an area circum- scribed by a one-quarter (%) mile radius around the well, meet the qualifications set out by 20 AAC 25.440(a)(2) for exemption of freshwater aquifers. NOW, THEREFORE, IT IS ORDERED THAT the portions of freshwater aquifers lying below a depth of 2300' in Unocal's Lewis River Well D-1 and within a circle of one-quarter (%) mile radius around the well be exempt for purposes of Class II underground injection activities only. DONE at Anchorage, Alaska, and dated March 30, 1989. ·c (21!œ~ Alaska Oil and Gas Conservation Commission Commission #13 WATER-RESOURCES INVESTIGATIONS REPORT 85-4114 u.s. GEOLOGICAL SURVEY . - . .: .../'>. .: :.," ,>' . :.>. . i . ' ,". '.. . . ~ . ", :., ' . . . . . '. , . _:_"~ u-.. _ ~._ :~:"~;..~.; :",,:,_-:,-j~..~,:;~~:._-.',;~: c_~>;.~.~. , ·_~.__i.1·__'. -:~;~fJI~t~¡¡i§!f}L~"'=~~~'.-r_~.,'-~.= -~:_'-_ .._,:-~-;._~:;~-;~-;.' - '. " (!) C E fi )I" p/1CTrTr fiLjlSKfl G U L F C9F OF CAPPS COAL FIELD, ALASKA RESULTS OF TEST DRILLING AND HYDROGEOLOGY --~ UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY RESULTS OF TEST DRILLING AND HYDROGEOLOGY OF CAPPS COAL FIELD, ALASKA By Gordon L. Nelson Water-Resources Investigations Report 85-4114 . Anchorage, Alaska 1985 UNITED STATES DEPARTHENT OF THE INTERIOR DONALD PAUL HODEL, Secretary GEOLOGICAL SURVEY Dallas L. Peck, Director For additional information write to: Copies of this report can be purchased from: District Chief U.S. Geological Survey Water Resources Division 4230 University Drive, Suite 201 Anchorage, Alaska 99508-4664 Open-File Services Section Western Distribution Branch Box 25425, Federal Center Denver, Colorado 80225 Telephone: (303) 234-5888 ü -..-/ CONTENTS Abstract. . . . . . . . . . . . . . . . . . Introduction.............. ............ ............. II.... ......... .......... .................... a............................. Purpose and scope........................................................... Previous work............................................................... Streamflow and surface-water quality........................................ T est d r i l1i ng. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . TVl 79-2................................................................ Drill Hole 2C-BO......................................."................ TIV 80-2................................................................ TW 80-3................................................................ '!'VI 80-4................................................................ T'tV 80-5...................................................... . . . . . . . . . . TIV 80-6................................................................ TIV 80-7................................................................ Hydrogeology. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . '_ . . . . . . . . . . . . . . . . . . . . . Ground-wa ter quality........................................................ Conclusions. . . . . . . . . . . . . . . . . , . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . References ci ted. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ILLUSTRATIONS Figure 1. Map showing location of Cook Inlet basin and Capps Page 1 1 3 3 4 5 7 7 10 10 12 12 15 15 15 21 21 23 coal .field.................................................. 2 2. Graph showing water-year precipitation at Belugat Alaska..... 4 3. Hydrograph separated into three components of streamflow..... 5 4. Map showing locations of drilling sites in Capps field....... 6 5-12. Graph of: 5. Well logst TW 79-2 and Drill Hole lC-79.................... 8 6. Well and geophysical logst Drill Hole 2C-80................ 9 7. Well and geophysical log, TW 80-2.......................... 10 8. Well and geophysical logs, TW 80-3......................... 11 9. Well and geophysical logst TIv 80-4......................... 13 10. Well and geophysical logs, TW 80-5......................... 14 11. Well and geophysical logst TW 80-6......................... 16 12. Well log, T'tV 80-7.......................................... 17 13. Geologic section through Capps field.......................... 18 14. Graph of drawdown data for TW 80-6 superposed on type curves of Papadopulos and Cooper (1967)..................... 20 TABLE Table Analyses of ground-water samples from Capps coal field....... 1. iii 22 CONVERSION TABLE Hultiply by to obtain inch ( in. ) 25.40 millimeter (mm) foot (ft) 0.3048 meter (m) mile (mi) 1.609 kilometer (km) acre 0.4047 hectare cubic foot per second 0.02832 cubic meter per second (ft3/s) (m3 / s) ton, short 0.9072 megagram (Mg) gallon per minute (gal/min) 0.06308 liter per second (L/s) square foot per day (ft2/d) 0.09290 square meter per day (m2 / d) degree Fahrenheit (OF) (OF-32)/1.8 degree Celsius (0 C) Other abbreviations in this report are: µg/L, microgram per liter mg/L, milligram per liter µS/cm, microsiemens per centimeter at 25 °c iv --- -' RESULTS OF TEST DRILLING AND HYDROGEOLOGY OF CAPPS COAL FIELD, ALASKA By Gordon L. Nelson ABSTRACT Capps coal field, one of the Beluga coal fields located 60 miles west of Anchorage, Alaska, is in a remote roadless area above the treeline. Two major coal seams, the 20-foot thick Capps seam and 40-foot thick Waterfall seam, will be mined to supply an export market. No high-yield aquifers were identified during drilling of seven test wells and two continuously cored drill holes, but several Tertiary units of coal and weakly consolidated sandstone and conglomerate collectively provided as much as 60 gallons per minute to wells. Melting of the winter snowpack continues throughout the summer and precludes measurement of base flow in Capps Creek until late winter, when stream discharge is less than 10 cubic feet per second. Sedge bogs and thin discontinuous glacial aquifers are probably the source of water for springs that sustain baseflow in the area to be mined. Heads in the deeper bedrock aquifers are commonly below land surface; these aquifers do not contribute to base- flow in the mine area. The concentration of dissolved solids in ground water ap- pears to increase with depth, but dissolved solids did not exceed 161 milligrams per liter in any sample. Both ground water and surface water are potable but ground water may require aeration to remove an odor of hydrogen sulfide. INTRODUCTION Alaska, which has about half of the nation's coal reserves, has only one small (about 700,000 tons annually) active mine. However, the potential for development of new mines îs great. One of the most likely places for such development within the next 10 years is the Beluga coal fields on the west side of Cook Inlet (fig. 1). In just one 50, OOO-acre part of this field, industry has identified 750 million tons of economically extractable low-sulfur coal within 30 mi of tidewater (Sanders, 1980). The Capps Creek coal field (hereafter called the Capps field) is one of the Beluga coal fields. The field is about 24 mi from tidewater and about 60 mi from Anchorage (fig. 1). There are no roads into the field, but tractor trails provide access from the nearest road near Tyonek. The Capps field is situated in rolling uplands that range in altitude from 1500 ft to 2000 ft above sea level. The east side of the field is deeply incised by Capps Creek and North Capps Creek near where they flow into the glacially excavated Beluga River valley. Sedge bogs occupy about 10 percent of the coal field (Gough and Severson, 1983), and the field is entirely above the treeline. 1 154° 62° 1520 1500 148° 60° o I I I I o 1 I I 50 KilOMETERS 50 MilES I Figure l.--Location of the Cook Inlet basin and Capps coal field. The Capps field is owned by Cook Inlet Region, Incorporated, an Alaska Na ti ve Regional Corporation, and is leased to Beluga Coal Company, a subsidiary of Placer Amex, Incorporated. Both owner and lessee of the field cooperated by granting the u. S. Geological Survey free access to the property and by providing proprietary data that aided in planning the field work. Funding for the Capps Creek stream- gaging station was provided by the Alaska Department of Natural Resources, Division of Geological and Geophysical Surveys. During the energy shortage of 1978-1980, the economics of developing the Beluga coal fields began to look attractive to investors. Two proposed markets were the Far East export market (primarily Japan and Korea) and a proposed methanol plant to be built near Granite Point. The Far East is still a potential market in spite of the current (1985) abundance of petroleum, because Japanese and Korean utilities wish to diversify their energy sources. The Capps field is attractive for early development because a coal seam that is 40 to 55 ft thick subcrops under generally less than 20 ft of overburden along a linear distance of about 1 mi. Although many test holes were drilled to obtain coal resource information, no hydrologic data were collected. - However, the drilling logs indicated that most of the materials within 200 ft of the surface were fine-grained Tertiary sediments of the Tyonek Formation. Few of the units appeared to have the permeability required to be classified as aquifers. No water wells have been drilled in the Capps field; the nearest water wells are in the Tyonek area. However, the near-surface bedrock 2 --~/ penetrated by wells in the Tyonek area is stratigraphically higher (younger) than in the Capps field. Adkison and others (1975) reported that the lower part of the Tyonek Formation contained coarser materials than the younger materials found near Tyonek. Ground-water information in the Capps area is needed to determine whether adequate quantities of ground water are available for use in mining operations and to deter- mine whether significant drainage problems may occur. Data on ground-water quality are necessary to determine whether naturally occurring pollutants exist in ground water and might be drained to the surface environment during mining. PURPOSE AND SCOPE The objectives of this report are to: 1. Define aquifers and confining units in the Capps Creek coal field. 2. Evaluate properties of aquifers and estimate whether significant quantities of ground water may be obtained from wells. 3. Describe chemical qualtity of ground water and surface water. This project included drilling of water wells and evaluating hydrologic results of other drilling in the field. Packer tests were conducted to determine the ver- tical distribution of heads and to selectively sample individual aquifers in un- cased wells. Ground-water and surface-water samples were collected and analyzed for major ions and three metals. PREVIOUS WORK Barnes (1966) summarized previous geological studies of the Beluga coal fields, mapped coal outcrops, and estimated coal reserves. In the Capps field he identified one major coal seam that he called the Capps seam. Subsequently, the Beluga Coal Company drilled the intersections of a land grid having i-mile spacing and identified two major coal seams that they named the Capps seam and the Water- fall seam (Placer Amex, Inc., 1977, written commun.) That terminology will be used in this report. Scully and others (1981) made a hydrologic reconnaissance of the Capps field. The ground-water aspects of their report were limited to studies of baseflow and springs because there were no wells in the Capps field. Baseflow information indicated that about 30 percent of streamflow was derived from ground-water sources. However, there was no information on which geological units were aquifers nor on which aquifers supplied most of the baseflow. Such factors could be evaluated only be test drilling. This study was made concurrently with studies by the U.S. Geological Survey, Office of Engineering Geology. The Engineering Geology studies focused on geotechnical properties of materials and on mapping of surficial geology (Chleborad and others, 1980; 1982). Hinkley and others (1982) analyzed whole-rock chemical composition of core samples from the two holes drilled by Chleborad. Severson and Gough (1983) and Gough and Severson (1983) analyzed geochemistry of soils and vegetation in the Capps field. 3 There are no meterological stations in the Capps field. However, the National Weather Service maintains a station at Beluga about 25 roi southeast of the Capps field. Data collected at Beluga indicate that for the very short period of record, precipitation has averaged 27.1 in/yr (fig. 2). However, a significant orographic effect causes precipitation at the Capps field to be greater. Fog and rain com- monly occur in the Capps field when Beluga is experiencing fair weather. 40 (/) w :r: I u 30 z I Z I z' I 0 I ~ <x:: I I t: I c.. 10 I u I I UJ I a: I 0... I I 0 I 1974 1976 1978 1980 Figure 2.--\Nater·year (October 1 to September 30) precipitation at Beluga, Alaska, 1974-81. STREAMFLOW AND SURFACE-WATER QUALITY Since 1979 a stream-gaging station has been operated on Capps Creek about 3 mi dmmstream from the proposed mine. Over the period of record, discharge ranged from about 5.0 to 710 ft3/s and averaged 61.2 ft3/s. Melting of winter snowpack continues until nearly the end of the following summer. Frequent rains during August and September keep discharge greater than baseflow until after freezeup in the fall. True baseflow, derived solely from ground water, occurs only during the winter (fig. 3). Stream water in the Capps field is always dilute, even at baseflow condi tions. Scully and others (1981) measured specific conductance over a wide range of discharges in several Beluga-area streams. They empirically determined that specific conductance (SC) is related to dissolved solids CDS) by: DS = 0.7 SC + 6 4 - C 10,000 z CAPPS CR E EK 0 u 1980 w en a: w 0- I- w w u. U co :::> u z w· " C) a: <í J: U en 0 Ground water 0 Oct Sept Figure 3.--Hydrograph separated into three components of streamflow. Lines illustrate a conceptual model of runoff but are not precise. All 13 specific conductances measured earlier for Capps Creek samples were within the range 20 to 70 µS/cm. All the specific conductances measured during this study were wi thin the lower one-third of this range. The 70 µS/ cm value measured on April 14, 1976, was for late-winter baseflow conditions (5.5 ft3/s) when all streamflow was derived from discharge of ground water. From these data and the relationship between dissolved solids and specific conductance, it appears that streamflow is always less than about 60 mg/L dissolved solids. TEST DRILLING All drilling was done by rigs mounted on tracked vehicles that could traverse the roadless and boggy terrain. Geophysical logs were run in each well except TIv 79-2 and TW 80-7. The natural gamma, gamma-gamma (density), and neutron (moisture) logs were used to identify formational contacts that could not be determined accurately during drilling. Lithologic logs of all wells for which geophysical logs were run have been modified to reflect formational contacts indicated by the geophysical logs. The drilling was done in cooperation wi th the U. S. Geological Survey, Office of Engineering Geology (OEG). Geologists from OEG supervised the continuous coring of two holes, drill hole 1C-79 in 1979 and 2C-80 in 1980; the results were reported by Chleborad and others (1980). The u.S. Geological Survey, Water Resources Division drilled test well 79-2 in 1979 and six other wells in 1980 (fig. 4). The 1980 drilling, which could not be started until September, had to be terminated on October 17 because a heavy snowfall forced a rapid evacuation of personnel and equipment from the field. Although all test wells were completed, packer testing and sampling of the wells had to be postponed until 1981. 5 t .. ....., .:._..f..... . '.',; '.-.-~-.'." . - . . t.· ..:.... . -:. ~::'::'. :'..: :.: . 1 C·79 @ 80-2 . . . .... .... '. ;.: Figure 4.-Location of drilling sites in Capps field. Geologic section A-A' is shown in figure 13. 6 '-.--" TW 79-2 The first test well, TW 79-2 drilled in 1979 and designed to penetrate both the Capps and Waterfall seams, is about 100 ft from drill hole 1C-79 that was contin- uously cored by Chleborad and others (1980). The drill hole was drilled using ben- tonite mud as a circulating fluid, and it was not possible to determine water yield from the formations. The well was drilled using air rotary methods. Figure 5 compares logs of test well 79-2 and the upper 250 ft of drill hole 1C-79. The two holes are only 100 ft apart and presumably the logs should show similar Ii thologies. The geologic contacts can be accurately determined in the contin- uously cored drill hole, but water-bearing units cannot be identified when drilling with a bentonite slurry. The water-bearing zones can be identified when drilling with air in the test well, but poor return of cuttings precludes accurate identifi- cation of the geological contacts. The combined use of lithologies and contacts from the drill hole and the water yields from the test well provides a more ac- curate assessment of actual conditions at the site. The diamicton in the upper 30 ft of the hole was generally unsaturated, except near the top of the Capps coal seam where seepage of less than 0.5 gal/min was detected. No other water-bearing zones were detected to the total depth of 250 ft in the test hole. Below the Capps seam the sediments consist of unsaturated sandstone, siltstone, and small-pebble conglomerate. The conglomerate is apparently quite permeable; drilling-fluid circulation in drill hole 1C-79 could not be maintained in the interval 200 to 397 ft and water was injected by gravity flow into the conglomerate in test well 79-2 at a rate of about 100 gal/min. The 1979 drilling site is near the northern edge of the Capps coal field and is near the bluff where North Capps Creek has deeply incised the sediments. The conglomerate penetrated in the test well, or its lateral equivalent, crops out downdip within a distance of about 0.5 mi. Drainage of ground water to the surface at the downdip outcrop probably keeps the coarse uni ts unsaturated between the drilling site and the outcrop. A major objective in selecting sites for subsequent wells was to penetrate similar conglomerates farther from the outcrop, where they might be saturated, and nearer land surface, where they might be recharged by streams and by direct infiltration of precipitation. All subsequent sites were more than 1 mi from the outcrop. Drill Hole 2C-80 Drill hole 2C-80 (fig. 6) was continuously cored, and the cores were analyzed to determine engineering properties of the materials. The lithologic and geophysical logs indicate that the well penetrated about 65 ft of overburden, the 40-foot thick Waterfall seam, and 95 ft of sediments that underlie the Waterfall seam (Chleborad and others , 1980). The water surface in the well is 110 ft below land surface, but is not a static water level. An aquifer above the water surface yields water that can be heard cascading down the well. A temperature log indicates water flows out of the well into a formation near 165 ft. 7 TW 79·2 DRILL HOLE 1C-79 0 . . ~ 0 .~ .:..... .. . - " Diamicton Diamicton ; 1:) .  -v. . , . . . 20 A ..~: . Claystone Claystone 40 60 Coal Coal with claystone partings ? ? Cuttings not returned, but coal ? Coal ? cuttings caked on drill collar and ? ? in casing Claystone and siltstone with 80 -- - fine sandstone 73-74 ft. -- - .,-..-... -..-.. : Interbedded fine-grained sandstone, siltstone, and claystone 100 Thinly interbedded fine sandstone, siltstone, and ¡- claystone I- w w w w u.. u. z 120 Interbedded claystone, siltstone, Z w- and coal. Very poor return of LU Ü cuttings Ü « « u.. u. a: 140 Interbedded coal. claystone, and 140 c:: ::> ::> (/'J sandstone Cf) 0 Coal 0 z z 5 Coal « ...J ~ 160 160 ~ g 0 ...J W W c:c OJ :t: :r: b: 180 Interbedded claystone and siltstone; I nterbedded siltstone and 180 I- el. W grading downward to very fine· fine-grained sandstone w 0 gra ined sandstone 0 200 200 Ò Very poor recovery of core, but . . Conglomerate, small-pebble, and interval is probably composed of . .Q.. ~. and coarse sandstone very friable sandstone, siltstone, 220 Sandstone, fine-grained, clayey and small·pebble conglomerate 220 0 Conglomerate, small-pebble, sandy 'ó or interbedded sandstone and conglomerate 240 - ----- - - -- 0 Hole logged to 394 ft . . Chleborad and others (1 9aO) - - -- - --- 260 Figure 5.--Welllogs, TW 79-2 and drill hole iC-79. B -- o : ~ ; 'f)" ,":, Colluvium - DRILL HOLE 2C-BO Natural Gamma Gamma-Gamma Neutron ~':~::~ :~: ':: ~~::-::~,7J" Sandstone, med.-v.fine 20 : ,:..::: ':' grained, gray, silty; silt .' . ':. : .' interbeds .. . .. .. . . ... -.- .' 40 _.._.._ 1._.._.. . . . .' . . C::.~:., O~U. ~ w ~~7::::. Siltstone, sandy, clayey w u. Z 60 w~ u « u. ~ 80 en CI Z :5 3: 1 00 o -J W co J: ~ ft 120 o laystone, silty Coal with claystone interbeds ..-.. -. .., . . .. .. . . . .. - .. -. ..-"-' ,--..-. -... . . .' _'. _.. Interbedded coal, silt 140 .:.:..::-.:..:... claystone, sandy :, ': '.,: :: siltstone, and si Ity :.:: :.. «' sandstone . '. I, 160 _.._1. . , . .' . . . ~ I.. 180 Coal 200 Figure 6.--Well and geophysical logs, drill hole 2C-80. 9 TH 80-2 In 11v 80-2 (fig. 7), the units stratigraphically equivalent to the relatively coarse sand and gravel in TW 79-2 were fine grained and yielded no water. The well produced about 20 gal/min from the Haterfall seam and the underlying conglomerate. During drilling, it appeared that most of the water came from the coal, and a relatively small additional yield was added when the bit penetrated the conglomerate. TW 80-2 Natural Gamma o Clay, brown, organic Gravel (Diamicton?) Interbedded coal, siltstone, and claystone Other geophysical logs not run t- LU LU u.. :2 w' u <! u.. a: :::> U) o z ~ ;: o ..J LU en :r: I- 0... UJ o 20 Water level 40 60 80 Figure 7 .--Well and geophysicallogt T\V 80-2. T\v 80-3 Test well 80-3, drilled about 40 ft west of TW 80-2, was intended to test materials underlying the \vaterfall seam by casing off the materials above 60 ft (fig. 8). However, the casing could not be driven past 49 ft, and the Waterfall seam was not entirely cased off. The completed well produced about 40 gal/min, about a quarter of which was from the Waterfall seam. The remainder of the water that could be detected during drilling was from a 10-foot thick coal bed 61 to 71 ft below land surface. Below 71 it no increase in well yield was apparent during drilling. However, when a packer was set and the well pumped in 1981, the interval below 98 it produced about 20 gal/min and the upper interval produced about 40 gal/min. 10 -~ TW 80-3 Natural Gamma Gamma-Gamma Neutron o - - - Claystone, gray, silty, 120 .,-.. - grading downward to .. =.:-:- clayey siltstone Sandstone, fine-grained. silty, sandy - Clay. brown. organic Gravel (Diamicton? Interlayered coal. siltstone, and claystone ..- w w u.. Z w u « u.. a: ::> CJ) CI Z ~ ~ o -J w en :r: t 100 w o 140 160 Figure 8.--Well and geophysical logs, TW 80-3. 11 The two most likely explanations of why the interval below 98 ft yielded no water during drilling but about one-third of the water in July 1981 are: (1) The yield of the upper zones, which had been producing water for several hours by the time the drilling reached 98 ft, was declining at the same time yield was increasing below 98 ft. This resulted in no apparent increase in yield. (2) The permeable materials below 98 ft were unsaturated during drilling but, by July 1981, had become saturated near the well after 9 months of downhole flow from the aquifers above 98 ft. If the latter explanation is true, then the sample collected from below 98 ft may be water from the overlying aquifers that has been slightly changed by contact with formerly unsaturated rocks. The similarity of the two samples (see table 1 later in the text) does not preclude such an explanation. Water could be heard cascading into the well, apparently from the Waterfall seam near the bottom of the casing, when the well was sampled in July 1981. An attempt to set a packer below the Waterfall seam at 59 ft failed, possibly because of erosion of the claystone by the cascading water. T\-1 80-4 Test well 80-4 was drilled about 1300 ft southwest of drill hole 2C-80 in an area in which the 1vaterfall seam has been removed by erosion. The materials penetrated are stratigraphically below the Waterfall seam (fig. 9). No aquifers were pene- trated during drilling. However, on October 10, 1980, 15 days after the well was completed, water had filled it to 75 ft below land surface. Because of the very low yield, the well was not pumped and sampled. TIl 80-5 Test well 80-5 (fig. 10) was drilled about 0.9 mi southwest of drill hole 2C-80. The site is upgradient and presumably isolated from proposed mining-related activities. The well penetrates materials that are stratigraphically the lowest of any penetrated during this drilling program. The well was drilled in a landslide deposit, and subrounded cobbles of coal from as deep as 60 ft indicate overriding or entrainment of Holocene stream deposits by the landslide. The saturated unconsolidated sand 8 to 22 ft below ft below land surface heaved into the well during drilling. Most of the water was obtained from the thinly interbedded claystone and coal between 107 and 114 ft. However, an additional small amount, probably less than 5 gal/min, was obtained from the sandstone below 114 ft. After completion, the well flowed naturally at a rate of about 3 gal/min. The water flowed from a 20-foot extension temporarily welded onto the casing, indicating that the head was more than 20 ft above land surface. Packer sets at 95 ft and 114 ft indicated heads were above land surface in both the coal and the sandstone below 114 ft. 12 TW 80-4 Natural Gamma Gamma-Gamma Neutron 0 Silt, brown, clayey ..-..-.. Clay, silty, sandy Silt, clayey, sandy Thinly bedded and interlayered claystone, 40 coal, silt, sand, and co nglo merate f- 60 w w u- Z w (,) 80 « u- a: :J VJ 0 z 100 S Claystone, gray, silty ~ 0 ...J W m 120 :I: Coal f- a.. w £::) 140 Claystone, gray, si Ity; with thin beds of coal 160 Coal Claystone, gray, silty Coal 180 Claystone, gray, silty a.-e. _ 200 Note: Scale was changed at water table to keep recorder pen on chart. Figure 9.--Well and geophysical logs, TW 80-4. ",-,-> 13 ~ w W LL Z w u <! LL a: ::) en o z :5 ~ o ....J W Q: :t: ~ a.. w Cl o " . . 0 . 20 ~ .0 '. 0 '~.'. ....1'f!Þ 40 60 -~. - 80 .. - .. Clay, brown, silty Sand, fine-medium grained, gravelly with coal cobbles Claystone, gray I silty - -- - - - -:.. <;- Bottom of casing ..-.. - 100 . . '';-. .-..:..:.. Sandstone, fine grained '~ . .. .... clayey Thinly interbedded .:-.... :.' cia stone and coal 120 . .. .:. Sandstone, fine grained, carbonaceous with clay interbeds --- 140 - -- 160 Claystone, gray, carbonaceous TW 80·5 Natural Gamma Gamma-Gamma Neutron Figure 10.-Well and geophysical logs) TW 80-5. 14 ---' TH 80-6 Test well 80-6 was drilled in an area in which the Waterfall seam is within 15 ft of land surface. The area is proposed for the earliest mining activity, and the drilling site is near a trench from which a 100-ton bulk sample of coal was mined in 1979. The well penetrated 11 ft of clay and diamicton overburden on top of the Waterfall seam (fig. 11). Casing was driven to 35 ft and did not case off any aquifers. Most of the water was obtained from a medium-grained sandstone 118 to 120 ft and a coal bed 135 to 142 ft below land surface. Sandstone units below 100 ft also may have contributed a small amount of water. The total yield of the well was about 10 gal/min. On July 8, 1981, a packer was set at 95 ft below land surface, and, with the pump set above the packer, the well was pumped at a rate of 5 gal/min to test the yield of the Waterfall seam. The water level, which was at 25 ft below land surface after the packer was set and just prior to the pumping test, fell below the base of the Waterfall seam at 45 ft in 19 minutes. (The water level indicated at 22 ft in figure 11 was a composite of all water-bearing zones.) During these 19 minutes of pumping, about 30 gal of water were obtained from casing storage and about 65 gal from the formations. Thus, it is unlikely that the units above the 95 ft depth can provide more than 3 gal/min on a sustained basis. TI.J 80-7 Test well 80-7 was drilled downslope and across a stream from TIv 80-6. The well penetrated materials (fig. 12) that are stratigraphically equivalent to those in TW 80-3 (fig. 8). The coarse-grained sandstone and small-pebble conglomerate over- lying the Waterfall seam appear similar to materials overlying the Waterfall seam in drill hole lC-79, but in TW 80-7 the materials were saturated and yielded water to the well. Casing was driven to 27ft, but a break in the casing at 15 ft allowed shallow water to enter the hole. The lithologies and contacts have not been verified by correlation with geophysical logs. HYDROGEOLOGY In all four wells that penetrated the Waterfall seam (TW 80-2, 80-3, 80-6, and 80-7), a significant fraction of the well yield was derived from the coal seam. No other unit could be both identified as an aquifer and correlated between two or more wells. The potentiometric surface of the \vaterfall seam is about 30 ft below land surface in TW 80-2 and 80-3, 22 ft below land surface in well 80-6, and could not be defined in other wells. However, it is presumably no higher than land surface at the outcrop, which along North Capps Creek is 700 ft below the altitude of the potentiometric surface at TW 80-3. Thus, it appears that a large hydraulic gradient will cause ground water to flow toward the north (fig. 13). 15 o I- w W L.L. Z w' u <t L.L. a: ::> C/') c z S ~ o -1 W co :r: I- ~ w o Diamicton, brown, clayey, silty, pebbly 20 Y.. Water level Coal, hard, black (Waterfall seam) 40 Claystone, gray, silty, .:....-. :.-= with thin beds of coal 60 - - - and bone coal 80 Claystone, gray, siltYI with thin coal beds . . Sandstone, gray, silty 120 . . . . 140 Coal Claystone, gray 160 180 TW 80-6 Natural Gamma Gamma-Gamma L.... . . . . . , . ... . .. . , '" . . . ". .' . ... . .., Figure 11.-Well and geophysical logs, TW 80-6. 16 Neutron -- TW 80-7 0 Clay. brown, organic Sand. pebbly. clayey f- w w 20 Bottom of casing u.. Z Geophysical logs w Thinly interbedded clay. coal not ru n U and pebbly sand <! 40 u.. a: ::::> en 0 z Coal (Waterfall seam) ~ 60 ~ 0 ...J W [D J: b: w Clay. silty. with sand bed £:) 94-98 ft -.-- .. _ .:.-=- _ Thinly interbedded clayand coal 120 Figure 12.nWelllog, TW 80-7. 17 ~ 0 CO 0 Ù CO N M A' ãi ~ C7) ~ ò ,.... 0 co Ò .r:. "ii C1> ~ Õ .r:. A 2400 ...J w 2200 > w ...J <t: 2000 w (J) w > 1800 0 m <t: 1600 I- w w u.. 1400 z LÙ 1200 0 =' }- 1000 ~ ,<t: 800 600 1 MILE I 0.5 I o I o I 1 KI LOMETER I 0.5 VERTICAL EXAGGERATION X5 Capps seam ¡waterfall SeárTl Figure 13.-Geologic section through Capps field. Section is along A-A' in figure 4. 18 .-- No formal aquifer tests were made. However, the drawdown in TIv 80-6 was measured as the well was being pumped (fig. 14) to collect a sample for analysis of water composition. The pumping rate was 5 gal/min and the pumped aquiferes) were between the bottom of the casing (35 ft) and a packer inflated 92 ft below land surface. Water derived from storage in the casing was a significant part of pumpage during the test. Analysis of the data by the method of Papadopulos and Cooper (1967) accounts for casing storage. The method cannot be used to analyze the storage coefficient of the aquifer, but a small range of values for transmissivity can be calculated for all reasonable values of the storage coefficient ( or a , which is the storage coefficient times a factor that is approximately unity). The "F(u,B)=l II match for the greatest and least possible a curves can be used to cal- culate a range of possible values for transmissivity (fig. 14). It appears that the transmissivity of the 57-foot interval of sediments is within the range of 15 to 46 ft2/d. No other aquifer tests were made, either because the yields were too low to sustain a useful pumping rate or because the packer could not be set. However, because TW 80-6 had a good yield compared to the other wells, it is unlikely that other aquifers had transmissi vi ties greater than the upper limi t of that in TW 80-6, about 50 ft2/d. In most wells, heads decreased with depth. In TW 80-3 and drill hole 2C-80, water could be heard cascading down the well from a shallow aquifer to a lower aquifer. In wells TW 80-2 and TIv 80-7 the water levels were 10 ft and 12 ft, respectively, below both the level of the nearby stream and the saturated materials near the stream. At TW 79-2, the low-yield aquifers wi thin 100 ft of land surface were perched over deeper, unsaturated materials. In TW 80-4, yield of the well was insufficient to determine the heads in any specific units, and in TIv 80-6, no change in head with increasing depth could be verified. Only in TW 80-5 was the head increasing with depth. T1v 80-5 is outside the area to be mined and is located near the base of a steep slope bordering an up- land plateau that is 500 ft above the altitude of the well. All wells were cased through the first unit that yielded water, thus precluding measurements of the water table. However, saturated materials commonly occur at shallow depths. In sedge bogs, which are widely scattered throughout the area, the water table is at land surface except during prolonged periods of dry weather. During drilling, small amounts of seepage that commonly entered the wells at the base of the unconsolidated materials also indicate saturated materials at depths less than 10 ft. Numerous springs that feed Capps Creek and its tributaries at altitudes above 1,800 ft cannot obtain water from Tertiary aquifers, in which heads are 10 ft or more below land surface. The most probable sources of water to the springs are sedge bogs and colluvial or glacial aquifers overlying Tertiary sediments. 19 100 I ........ - - ~ ~::.:.~:.:..:.:...:.:..:...:.. 7(.... 'X ·~··x ··X..x: ~··x 'x. ''>f'X'' ~'X:. "'X:.... X-'-::." type-curve match x' '. )(";"'. F(u a) = well function ,". w, .... '. .....~... " '. .... ". " . ..... ". X " '. " " ". X " . ..... . " " " a =10-1 a =10-5 I 10-2 I ....... . ............... . . .". .. " " " " " "."" ---- ------- ------ H µ:¡ µ:¡ µ.¡ Z H 10 I- ... ".... 2; ~ _Cf) tv 0.......... a;;:: 10-1 Tmax = 0 § ~ 1 F(u,a) = Q Sw = 5.1 ft Tmin 5(1440) 411"( 7 . 48 ) 5(1440) 411"(7.48) (1.66) 46 ft/d (5.1) 15 ft/d a = 10-5 1- F(u,a) = 1 Sw = 1.66 ft 1.0 10-5 I 10-4 J 10-3 I EXPLANATION x = data points - -.:.~~~.. Bounding curves for , . -1 5 \ a = 10 and a::: lO- T = -..!L 47J'Sw Feu a) w where ' Q = pumping rate in ft 3/d Sw = drawdown, in feet, from - RECIPROCAL TIME, IN SECONDS 10-1 Figure 14.--Drawdown data for TW 80-6 superposed on type curves of Papadopulos and Cooper (1967). Pumping rate is 5 gal/min. -- ~ GROUND-WATER QUALITY Test wells 79-2 and 80-4 and drill hole lC-79 did not yield enough water to sample. All other wells were sampled in July 1981. Air-inflatable packers were used to isolate zones in each well. The wells were pumped using a 3-inch submersible electric pump. Temperature, specific conductance, and pH were monitored during pumping, and no samples were collected until all three properties were no longer changing with time. In some wells, differences in pH values and specific conductances indicated compositionally different water in shallow and deep water-producing zones. Where this occurred, both zones were sampled. If deep and shallow zones indicated similar values of pH and specific conductance, the packer was deflated and the well was sampled as a composite of all water-producing zones. All samples had a hydrogen-sulfide smell; however, after aeration none were objectionable for drinking. Table 1 lists results of analyses of the samples. All trace metal concentrations are less than the maximum concentrations recommended for drinking water (U.S. Environmental Protection Agency, 1977). Zinc is the only trace metal present in concentrations greater than 10 µg/L. However, it was not ascertained whether the zinc occurred naturally or if it was derived from galvanized pipe in the wells. The sample from TIv 80-5, the only well drilled outside the area of the proposed mine, appears to differ significantly from the other samples. It has a much higher pH than the others (8.4) and the second highest concentration of dissolved solids (154 mg/L). The sodium concentration is anomalously high and the calcium anomalously low compared to the other samples. Specific conductance, a general indicator of concentration of dissolved solids, was greater than 53 psi cm in all samples from Tertiary aquifers. Springs that dis- charge ground water from the Tertiary aquifers should also yield water of specific conductance greater than 50 µS/cm. The author made a traverse up the streambed of Capps Creek from about 100 ft stratigraphically below the base of the Waterfall seam to a point stratigraphically near the top of the Waterfall seam about 400 ft northwest of TW 80-3. Many springs were sampled during this traverse, but none yielded water having specific conductance greater than 24 µS/cm. This evidence indicates that the relatively high conductance ground water is not discharging in significant quanti ties in the area of the proposed mine and that the springs appear to be fed by aquifers containing water more dilute than the Tertiary bed- rock. These different aquifers are probably sedge bogs and thin unconsolidated deposits overlying the Tertiary sediments. Bog deposits were not penetrated during drilling because they occur in areas where foundation conditions are not good for setting up a drill rig without causing significant environmental damage. CONCLUSIONS Coal, sandstone, and conglomerate uni ts of generally low hydraulic conduc ti vi ty commonly yield water to wells but may be unsaturated near their outcrops. Based on the small amounts of subsurface information, only the Waterfall seam could be identified as an area-wide aquifer. An aquifer test of sediments that included the Waterfall seam indicated a transmissivity of less than 50 ft2/d. Sedge bogs and thin discontinuous glacial aquifers probably yield ground vlater to springs that sustain baseflow in the mine area. Heads in the deeper bedrock aquifers are com- monly below land surface, and deep aquifers do not contribute to baseflow of streams in the mine area. 21 22 Table 1.--Analyses of ground-water samples from Capps coal field Well.. ........ . . .. . . . .. . . . . . . TW 80-2 TW 80-3 TW 80-3 TW 80-5 TW 80-6 TW 80-6 TW 80-7 Depth of sample (ft) 32-64 47-98 98-151 88-155 37-95 95-168 26-90 Date (1981) 7-14 7-14 7-14 7-12 7-8 7-8 7-15 Specific conductance (µS/cm at 25·C) 104 97 107 218 163 247 53 Temperature (·C) 4 4 4 4 4 4.5 4 pH (units) 5.7 5.6 5.6 8.4 6.5 6.8 5.3 Dissolved solids (resid. at 180·C) 76 71 80 154 110 161 53 Silica (mg/L) 14 14 14 23 24 20 13 Alkal1ni ty (mg/L as CaC03) 55 54 61 126 88 108 34 Dissolved major ions (mglL) Calcium 13 12 12 1.8 14 11 9.0 Magnesium 2.0 1.9 1.8 .3 1.7 1.3 1.1 Sodium 11 7.4 11 55 20 35 3.4 Potassium .6 .5 .6 .3 .6 .7 .4 Sulfate 2.3 2.1 1.6 3.0 1.5 1.4 3.3 Chloride 10 .3 1.1 .8 .2 .3 .4 Fluoride .0 .0 .0 .1 .0 .0 .0 Nitrate + nitrite .05 .01 .02 .02 .02 .28 .01 Dissolved trace metals ()J~/L) Arsenic 3 2 2 0 1 2 3 Cadmi um 0 0 0 0 0 0 0 Chromium 10 0 0 10 10 0 0 Copper 0 0 0 0 0 0 0 Lead 1 0 2 1 0 1 0 Mercury .1 . 1 .1 .1 .1 .1 .1 Selenium 0 0 0 0 0 0 0 Zinc 50 20 40 10 30 10 20 ,..- Both ground water and surface water are of drinking-water quali ty. However, aeration of ground water to remove a hydrogen sulfide odor is usually desirable. The concentration of dissolved solids in ground water appears to increase with the depth of wells, but did not exceed 161 mg/L in any of the samples. Surface water is much more dilute; concentration of dissolved solids probably does not exceed 60 mg/L at lowest baseflow during late winter. REFERENCES CITED Adkison, W. L., Kelly, J. S., and Newman, K. R., 1975, Lithology and palynology of Tertiary rocks exposed near Capps Glacier and along Chui tna River, Tyonek quadrangle, southern Alaska: U.S. Geological Survey Open-File Report 75-21, 58 p. Barnes, F. F., 1966, Geology and coal resources of the Beluga-Yentna region, Alaska: U.S. Geological Survey Bulletin 1202-C, p. C1-C54. Chleborad, A. F., Yehle, L. A., Schmoll, H. R., and Gardner, C. A., 1980, Pre- liminary field geotechnical and geophysical logs from a drill hole in the Capps coal field, Cook Inlet region, Alaska: U.S. Geological Survey Open-File Report 80-393, 20 p. Chleborad, A. F., Yehle, L. A., Schmoll, H. R., Gardner, C. A., and Dearborn, L. L., 1982, Preliminary geotechnical and geophysical logs from drill hole 2C-80 in the Capps coal field, Cook Inlet region, Alaska: U.S. Geological Survey Open-File Report 82-884, 9 p., 2 pl. Gough, L. P., and Severson, R. C., 1983, Chemical analyses of na ti ve soil and vegetation samples, Capps coal field, Alaska: U.S. Geological Survey Open-File Report 83-246, 54 p. Hinkley, T. K., Smith, K. S., Peard, J. L., and Tompkins, M. L., 1982" Whole-rock chemical composition of some samples from two drill-hole cores in the Capps coal field, Beluga coal area, South-central Alaska: U. S. Geological Survey Open-File Report 82-672, 50 p. Papadopulos, I. S., and Cooper, H. H., Jr., 1967, Drawdown in a well of large diameter: Water Resources Research, v. 3, no. 1, p. 241-244. Sanders, R. B., 1980, Coal resources of Alaska, in Rao, P. D., and Wolff, E. N., eds., Focus on Alaska's coal '80--Conference, Fairbanks, Alaska, 1980, Proceedings: University of Alaska }fineral Industry Research Laboratory Report 50, p. 11-31. Scully, D. R., Krumhardt, A. P., and Kernodle, D. R., 1981, Hydrologic reconnaissance of the Beluga, Peters Creek, and Healy coal areas, Alaska: U.S. Geological Survey Water Resources Investigation 81-56, 71 p. Severson, R. C., and Gough, L. P., 1983, Chemical composition and variability of soils from the Capps coal field, Alaska: U. S. Geological Survey Open-File Report 83-190, 36 p. U.S. Environmental Protection Agency, 1977, Quality criteria for water, 1976: U.S. Government Printing Office, 256 p. 23 #12 .-==-~ TELECOPY NO. (907) 276-7542 May 2, 1989 Randall M. Weiner Trustees for Alaska 725 Christensen Drive Suite 4 Anchorage, AK 99501 Re: Aquifer Exemption Order No. 3 Unocal Lewis River Well D-l Lewis River Gas Field Dear Mr. Weiner: Thank you for your April 24, 1989 subject letter requesting a rehearing in the matter of Aquifer Exemption Order No. 3. You have set forth some 11 issues which you propose for rehearing consideration. Our review of the record indicates that each of these issues has previously been brought to the Commission's attention. Our review of the file reveals that each of these issues was given careful scrutiny and consideration in the Commission's deliberations before taking final action in response to Unocal's acquifer exemption application. With each of the issues you propose for eonsideration, you justify the need for a rehearing by questioning whether the Commission exceeded its authoritYJ acted unlawfullYI acted improperly, erred in judgement; erred in failing or failed to address the issues. It is the Commission's conviction that issuance of Aquifer Exemption Order No.3 is within its authority; that the Commis- sion acted lawfully and properly; addressed responsibly each issue you raise, and did not err in failing, or failed to address the issues. The Commission considered your arguments for the Randall H. \¡,leiner~= Trustees of Alaska - 2 - ~...I 11ay 2, 1989 reconsideration of each of the issues you raise. The Commission finds no reason to change its earlier conclusion with regard to Aquifer Exemption Order No. 3 Therefore, we respectfully deny your request for a rehearing of the April 3, 1989 Aquifer Exemption Order No.3. Sincerely, (~\ / r-"' .. / /1/ ) . ~i./ ! f¡- , , ) ;1:, ,ff1.4,d/jÝ'-:;:' '-_.. . . ". <' / ,.'J ., , :. '/"~. . C. V. Chatterton Chairman dlf:l.CVC.122 /. .~ /.¡i{~,~ ..... " ~ '."'G/ ../¡¡.~~.".i-~\ ;._ ....--:._.....'__ ~ - ""__..._0......... j " Lonnie . Smith Commissioner eCI Steve Porter, Department of Law G. A. Graham - Unocal Robert Burd - EPA David tv. o..~. hn ton Connnis s loner' #11 OFFICE OF THE GOVERNOR STEVE COWPER, GOVERNOR ~u&uŒ mJ~ ~~~~~~ ,,- CENTRAL OFFICE P.O. BOX AW JUNEAU, ALASKA 99811-0165 PHONE: (907) 465-3562 DIVISION OF GOVERNMENTAL COORDINA TlON SOUTHEAST REGIONAL OFFICE 431 NORTH FRANKLIN P.O. BOX A W. SUITE 101 JUNEAU, ALASKA 99811-0165 PHONE: (907) 465-3562 REGISTERED MAIL RETURN RECEIPT REQUESTED SOUTHCENTRAL REGIONAL OFFICE 2600 DENALI STREET SUITE 700 ANCHORAGE, ALASKA 99503-2798 PHONE: (907) 274-1581 April 26, NORTHERN REGIONAL OFFICE 675 SEVENTH A VENUE STA TlON H FAIRBANKS, ALASKA 9' 9.. .7...0. ..145~. PHONE: (907) 456-39-8~1",""~. 1 9 8 9 ! C, I (-f; ,-,1 Igg~;~f ...; ri0DC~h"è ~ l3J . "... ~~"-" .. I Í~:}~~~-Ä~ST }B¡ 1------- ~ I ~_'~Jr~;iitl ! C;:~::C:_. AGE)· .'¡ > . Mr. Robert S. Burd Director, Water Division u. S. Environmental Protection Agency Region 10 1200 Sixth Avenue Seattle, WA 98101 Dear Mr. Burd: SUBJECT: EPA UNOCAL, FRESHWATER AQUIFER EXEMPTION LEWIS RIVER UNIT WELL D-l STATE I.D. NUMBER AK890405-03A CONCLUSIVE CONSISTENCY DETERMINATION The Division of Governmental Coordination (DGC) has completed coordinating the review of your project for consistency with the Alaska Coastal Management Program (ACMP). The activity is to approve the exemption of the freshwater aquifers deeper than 2300 feet for a one-quarter mile radius around Well D-1 at the Lewis River Field for Class II injection activities. Due to total dissolved solids concentrations in excess of 3000 milligrams per liter, this exemption is not being treated as a revision to the state program. It is a minor aquifer exemption because it is related to a permit action for a ~lass II. injection well. Based on the review of your project by the Alaska Departments of Natural Resources, Environmental Conservation, and Fish and Game, and the Matanuska-Susitna Borough, the state concurs with your certification that the project is consistent with the ACMP. If you have any questions regarding this determination, please contact me at 274-1581. RECE\VED zrel) {~ ú{Í11~fh Project Review Coordinator APR 2 7 199,0 Alaska on & Gas Cons. COOl mission - I"~ " ~chorage Ot-A35LH ---- '---- . .. Mr. Robert S. Burd 2 EPA Unocal, Freshwater Aquifer Exemption State I. D. No. AK890405--3A Enclosures cc: Julie Howe Department of· Environmental Conservation Bill Ashton Department of Environmental- Conservation Dave Johnston Alaska Oil & Gas Conservation Commission Faye Sullivan UNOCAL co12/19 April 26, 1989 #10 A Non-Profit, Public Interest, Environmental Law Firm April 24, 1989 'è sa f .:.~ '~ )::. ~~. "1:J ::So Ci) ;0 /r,J 0 fVifA n, Ðl l{g~~1Z; ~ i ~ ¡···'~~-;-~-tj··~~ ,! - f b ¡~;: t;:;.'.~ - -' ¡ ~ D I:~:\-~':~,~ f5. r-:' .' .-'~<~¡!'-~ ~ F-~~~~/(ft~¡ I ! ; .ç~: .. ~ I /¡ (~'" ......, i i -.: =' -- ¡- .~ '-~ I':':;¿'TT~~-~'-' r' ¡~r T~è-S,' ; jr' L ,:: ! ~ -~ -.__. "_ -~---L._, ;;0 ,." ~ ...... " -·-1 ~ -<: n:r o C. V. Chatterton, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3912 Re: Aquifer Exemption Order #3 UNOCAL Lewis River Well D-1 Lewis River Gas Field Dear Commissioner Chatterton: Trustees for Alaska received wri tten notice of the above referenced Aquifer Exemption Order #3 on April 3, 1989. Pursuant to AS 31.05.080(a), we hereby request a rehearing of this matter. :...... The person making this request is: Robert Disotell Randall M. Weiner Trustees for Alaska 725 Christensen Drive, Suite 4 Anchorage, Alaska 99501 907-276-4244 RE€~EIVED Trustees for Alaska 725 Christensen Drive, Suite 4 Anchorage, Alaska 99501 APR 2 If l~Q AlislœD.ü& G~ Cons.C.tm)ß)iSSLQß ·<~ï~~-~IU~Gf<·; Th~ persons represented are the members of: Trustees for Alaska is a nonprofit, public interest¡ environmental law firm whose purpose is to promote environmentally sound decisionmaking and compliance wi th environmental laws in Alaska. Many of TfA's members reside in Alaska and enjoy the use and benefits of the State's natural resources. The following issues are proposed for consideration at the rehearing. 1. Issues of jurisdiction 725 Christensen Drive, Suite 4 .~,; Anchorage, Alaska 99501 (907) 276-4244 100% Recycled Bond "'---. .~ a. Whether AOGCC has exceeded its authority by conducting a public process and public hearing regarding- the Le~'7is River D-l well Aquifer Exemption in lieu of the process and hearings conducted by EPA. 2. Issues of public notice a. Wh~ther the public notice for the Aquifer Exemption for the Lewis River D-l well was improper and not in conformance with the public notice requirements for Aquifer Exemptions set forth in 40 CFR 124. b. Whether the wording of the public notice for the Aquifer Exemption request was improper and unlawfully excludes comment on issues of public concern. c. Whether the public notice for the Aquifer Exemption request was improper in that it was not noticed in the area of the proposed injection, such as in the village of Tyonek. d. Whether the public notice which states that a hearing may only be requested by Ila person who may be harmed if the requested order is issued" is improper and unlawfully avoids the requirements for proper notice of a public hearing. e. Whether the public notice was improper in that it failed to provide an adequate description of the requested Aquifer Exemption. f . Whether the issuance of Aquifer Exemption Order #3 was improper in that it was neither properly published nor published wi th a description of the appeal process incorporated into the notice. 3. Issues of procedure a. Whether the AOGCC has failed to adequately review the materials submitted in support of the Lewis River Aquifer Exemption request and has reached an erroneous conclusion. b. Whether the AOGCC has failed to compile an adequate response to comments and has failed to summarize and respond to substantive comments received (see also ii.b). c. Whether AOGCC has failed to establish a viable permitting process that fulfills the requirements of both state and federal law. 4. Issues of TDS determination ") ¿, w· .--- ~- a. Whether AOGCC has unlawfully substituted a method of determining receiving formation water Total Dissolved Solids (TDS) content for that specified in the federal regulations. b. Whether AOGCC has failed to insure that the aquifer exemption for the Lewis River D-l well is consistent with aquifer exemptions for any other class of well, and would be consistent if the application for the Lewis River D-l well were for a Class I hazardous waste well. c. Whether AOGCC has erred by utilizing supporting data from the Pretty Creek Field for produced waters, and whether AOGCC was in error when it stated the data was for waters from the same strategraphic interval. d. Hhether AOGCC has erred by failing to consider the significance of produced water sample results data from the Lewis River Field that report the TDS of the waters as 1730 mg\L (1730 ppm), rather than 3-10,000 mg/L as determined by AOGCC~ en Whether AOGCC has erred by improperly relying upon inconsistent data provided by UNOCAL which relies upon an improper method of computation not permitted by the regulations. UNOCAL December 1, 1988, Table 1. 5. Issues. concerning the practicali ty and economics of utilizing the Lewis River aquifers as a water supply. a. Whether AOGCC has erred in failing to place the burden of proof on the applicant to demonstrate that the aquifer proposed for exemption cannot be practically used as a drinking water aquifer or would be uneconomical to so use it. 6. Issues concerning the confining formation characteristics a. Whether AOGCC has erred in failing to require proof that the proposed "permeabili ty barrier" is a competant forma tioD capable of acting as a confining strata for the injected fluids. b. Whether AOGCC has erred in failing to require geological data demonstrating the areal extent of the confining strata. c. Whether AOGCC has erred ìn failing to require proof that the proposed "permeability barrier" can be successfully sealed in the drilling affected area so that the passage of injected fluids along the wellbore can be prevented. ') ..J · ' -. '"-' 7. Issues concerning exceeding authority in Alaska Department of Environmental Conservation wastewater per~it issues. a. Whether ADEC should approve of the Aquifer Exemption nonwithstanding AS 46.03.100(d), which applies to injection projects. 8. Issues concerning sole source aquifers a. Whether AOGCC has erred in not considering the Sole Source Aquifer issue .and in not publishing a wri t ten response to the comments posed on the issue. 9. Wellhead Protection Program issues a. Whether AOGCC has erred in not considering the Wellhead Protection Program issue and in not publishing a written response to comments posed on the issue. 10. Record of responses issue a. Whether AOGCC has failed to compile ~ viable public record on the issues surrounding the Lewis River D-l -,.;-ell Aquifer Exemption application and has failed to compile the dc:~mentation requisite to support the determinations made in Aquife~ Exe~pticn Order #3. b. Whether AOGCC has failed to consider =-.·.lmercus issues raised during the public comment and hearing prOCESS and has failed to publish a written record of response to these issues a~ong others: (1) . Comments regarding language l~ the AOGCC description allowing the exemption of "hydrocarbon formations" rather than hydrocarbon produci~g for~ations. program bearing (2). Comments regarding aquifer modeli~g. (3). Comments regarding alternate mea~s of fluid disposal. (4). Comments regarding the granting :f aq~ifer exemptions outside of an established oil and gas unit. (5). Comments regarding the vertical ~~gration of fluids between zones sealed bl drilling mud. (6) . Comments regarding the compatib~:'i ty of the proposed injection fluids with the receiving formati~~s. (7) . Comments regarding the compatit~:'ity of the proposed 4 --" .~ injection fluids with the fluids in the receiving formation. (8) . Comments regarding the composi tion of the proposed injection fluids. (9) . Comments regarding the issuance by AOGCC of "Orders" rather than permits4 11. Alaska Coastal Zone Management issues a. Whether AOGCC has erred in not allo~ling for a Alaska Coastal Zone Consistency Determination prior to issuing an Aquifer Exemption Order. We appreciate your consideration of these matters¡ and are always willing to discuss these issues with you or your counsel. Very Truly Yours: Ra~~~ ...~ /'. µ'^it -Robert Disotell cc: Steve Porter I Dept. of Law G.A. Grahaml UNOCAL Robert BurdI EPA Allisonl DGC 5 #9 r~-·--- - ð ") \~# ~_.....-~ - -- ---- . 'f u.s. E~IRONMENTAl PROTECTION AGEt~Y REGIÓN 10 1200 SIXTH AVENUE SEATTLE, WASHINGTON 98101 AfAR R 8 1989 REPLY TO ATTN OF; WD..132 c. V. Chat tertan A1Iska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage. Alaska 99501 Re: Unocal Corporation Aqu'fer Exemption Request December 1. 19a5, for Le~1s River Field (Well D-1) Dear Hr. Chatterton: We have received and reviewed the Commission's February 16. 1989. letter recommending the approval of an exemption for the aquifers deeper than 21300 feet for ð one-quarter mile radius around Well 0-1 at the Lewis River Field for Class 11 1nJect1on well activities on1,. Under· the Environmenta1 Protect1on Agency's (EPA) gu1dance addressing aquifer exemptions this would be a minor aquifer exemption because it is re1ated to a permit action for ,a Clats II injection well. Due to the fact that this aquifer has total d1sso1ved so11ds (TDS) concentrations in excess of 3.000 milligrams per liter. the proposed exemption is not treated as a revision to the state program. However. 1t must rece;ve approval from EPA. It would become final without EPA approval if EPA failed to disapprove it within 45 days of the date of your letter (See 40 CFR §144.7(b)(3)(11}). As you recall. when EPA delegated the administration of the Class II 1nject1on well program to the Comm1ss1onþ we incorporated the relevant Alaska re9ulat1ons by reference (see 40 CFR §147.100). Consequently. when we cons1der an exemption request, our obligation is to confirm that the request - would comply with the Alaska regulations for exemptions. If the exemption request complies with these regulations. then EPA can be assured that. with the exemption, the Alaska Class II injection well program will continue to protect public hea1th and the environment. Bðsed on our review of the adm1n1strative record and the findings and information presented in the Commissionts February 16th letter, we conclude that the exemption request would meet the requirements of ·the Alaska regulations. Therefore, with this letter we accept the Commissionts recommendation and convey EPAls approval of the exemption. Additionally, EPA. like other federal agencies. is required to ensure that ;ts actions are consistent with federally approved state coastal zone management programs. Based on our rev1ew of the records and our discussions with representatives of Alaska's coasta\ zone management agency. the Division of Governmental Coordination in the Governor's Office. we have concluded that our action approving this aquifer exemption is consistent with A1oska's COIstB1 lone Management program~ ~ ~ , 14:Ø~ UZ'::Jt:) 1111, lIiCli I:.....J\ 1t1:.\AIUI'I J.t1 't!:I VVVI I, '----..-~ ~ - 2 - r{ We art aware of numerous public çomments on the proposed aquifer exempt10n and the need to reso1ve public misunderstanding about the exemption prOCel$. We agree with your recommendations on how we shou1d address these concerns and wfl1 work with ,you to amend the 110A to better clarify the aquifer exemption "process. . 51 ncerely II r~J.I.·^:(ßß'-1.~1 Robert S. Burd Direçtor. Water Division cc: Al11son Smith, D1v1S1on of Gover"ment~l Coordination Randall Weiner, Trustees for Alaska Kr1si1ne A. Benson, Alasko Cente~ for the Environment G.A. Graham. Unoca1 Corporation ~ ! \., .' ~ .I .$(7 '3 #8 Unocal Oil & Gas Di ;n Unocal Corporation '-" P.O. Box 190247 Anchorage. Alaska 99519-0247 Telephone (907) 276-7600 UNO[AL~ Environmental Department Alaska District DOCUMENT TRANSMITTAL January 20, 1989 TO: C. V. CHATTERTON FROM: ROY D. RJ8ERTS LOCATION: AOGCC 3001 PORCUPINE ANCHORAGE, AK 99501 LOCATION: UNION OIL COMPANY P.O. BOX 190247 ANCHORAGE, AK 99519 TRANSMITTING: Addendum to Unocal's Request for Freshwater Aquifer Exemption Upper Beluga Formation Lewis River Field .RECEIVED JAN 2 J 19µa ~JJjJ & Gas Cons. Commission '.~ ~·,-r-· .. -'-:--1~¡4~ ~cI1oragø Please acknowledge receipt by signing and returning one copy of this Document/1fan~~i~l. RECEIVED BY: .j - l ?") J DATE: I '"" ~ {r, /' .~ . L-- (/ .. {..? G'{ 5 Çh~A - ! JAN 2 J 19RQ ~ska Dil & Gas Cons. Commission --..¡,,; ~choragê RECEIVED SUBMITTED 1/20/89 LEWIS RIVER FIELD REQUEST FOR FRESHWATER AQUIFER EXEMPTION UPPER BELUGA FORMATION ADDENDUM TO UNOCAL'S J .-./ LEWIS RIVER DISPOSAL WELL INTRODUCTION This submittal provides additional information concerning Unocal's application for a fresh water aquifer exemption at the location of the Lewis River 0-1 well. The fresh water aquifer exemption is sought since the exemption is foundational to the project as a whole and because the fresh water aquifer exemption may be considered independently of other aspects of the project. Because of the foundational nature of this exemption, it is unnecessary and uneconomic to proceed with other app~Gation~ until a decision is reached on -/} C!-\) the exemption. When a fresh water aqulf~r;îs granted, a substantial number of [ õ additional permits will be required providing the opportunity for review. Additional permits which will be required to place this project in operation and involved government agencies include the following: Special Areas Permit from the Alaska Department of Fish and Game, and Temporary Water Use and Right of Way Permit from the Department of Natural Resources, Division of Land and Water Management. Further, Sundry Notices are required before any well work or perforation can be performed. Consequently, it is obvious that the fullest of review by government agencies will take place including reviews called for by the Coastal Zone Management Act and the appropriate area plan. PROCEDURAL As a brief response to the procedural comments which have been made concerning the appiications, Unocal notes that the procedures established for the applications have been approved by both the State of Alaska and the United States and that the procedures have been followed. That the procedures have accomplished their purposes of accumulating relevant information, providing notice to interested parties, and providing for an opportunity to be heard, is demonstrated by the actual proceedings which are taking place. BACKGROUND OF THE AREA, FACILITIES, AND CURRENT OPERATIONS The geographical area in which application is made lies immediately west of the Susitna River. The terrain is featureless wetland which in 1976 was included in the Susitna Flats State Game Refugee. Predating establishment of the Game Refuge, lands in the area were leased for oil and gas exploration, development and production, and operations under these leases have taken place and compatibly continue. A topographic map showing the terrain, the Game Refuge boundary, and the location of unit boundaries of various producing oil and gas units is provided as Attachment A The only improvements in the area other than improvements incident to oil and gas exploration, development an production, are a number of "duck shacks" seasonally utilized by waterfowl hunters. No permit residences in the area are known or should they ever be expected given the marshy character of the area stretching some miles in any direction and the designation of the lands as game refuge. In addition to the unsuitability of the surface terrain for "people" uses and its designation as game refuge, the evidence submitted by Unocal shows some 1000 feet of unconsolidated sediments containing available intervals of potential fresh water. Any hypothetical user of drinking water in the area would rather obviously target these shallow aquifers for water sources. TECHNICAL DATA - ANALYSIS fe'S Stratigraphy, the geology of the subsurface, is described in the Application for Underground Injection. In summary fashion, the topmost material consists of unconsolidated glacial debris, followed by the Sterling Formation, followed by the Beluga Formation. Both the glacial debris and the Sterling Formation contain multiple porous intervals containing good quality fresh water to a depth of some 1200 feet. The thickness of glacial debris and the Sterling Formation at the 0-1 well is some 1900 feet. Any water wells installed in the area would utilize these aquifers an would be expected to utilize the first encountered aquifer at shallowest depth. The Beluga Foundation is encountered at approxlmately 1900 feet at the 0-1 well. A more thorough discussion of the stratigraphy is found in Attachment B. LOG ANALYSIS Standard electric log analysis techniques were used to estimate the equivalent salinity of the water in the formation below 2300' in accordance with 20 AAC 250 (c)(lO). This method was verbally approved by the commission and has been an accepted practice by the Environmental Protection Agency, i.e. Beluga River Field Well BRWD-l Freshwater Aquifer Exemption. The equilivant salinities in NaCl of the formation waters for injection intervals between 2576' and 3912' range from 4,600 - 11,000 ppm. Conductivity is a measurement of the ability of an aqueous solution to carry an electric current. This ability depends on the presence of ions, their total concentration, mobility, valence, the relative concentrations, and on the temperature of the measurement. For most natural waters it has been found that when conductivity (in micromhos per centimeter at 25 C) is multiplied by a factor ordinarily in the range of .55 to .7, the product is equal to milligrams per liter (mg/l) total dissolved solids. The physical measurement made in a laboratory may be expressed as conductivity or resistivity, either of which is readily convertible from one to the other. Resistivity (in ohms-m) is equal to 1000/conductivity (in mmhos/m). '---- Electric log analysis techniques also record resistivity measurements which are then used to calculate formation fluid salinities. Salinity is defined as the total solids in water after all carbonates have been converted to oxides, all bromide and iodide have been replaced by chloride, and all organic matter has been oxidized. This method of analysis is very conservative since it does not account for some ions and elements normally found in natural groundwater resulting in a numerically smaller concentration than the actual total dissolved solids. Electric log interpretation of formation fluid resistivity and the subsequent determination of salinity is a standard technique (e.g. Hilchie, D.W., 1978, Applied Openhole Log Interpretation). Typically, salinities are given in equivalent parts per million (ppm) NaCl or Cl- which are corrected for temperature using available nomographs. Virtually any log analysis text describes the process of determining a subsurface temperature gradient the same way ( e.g. Hilchie, D.W., 1978, Applied Openhole Log Interpretation). It involves a linear interpolation between mean surface temperature and a known downhole temperature. The latter is obtained from the bottom-hole thermometer attached to each logging tool string as reported on the log header. It is common practice to use the highest downhole temperature from all the log runs because circulated drilling fluid conducts heat away from the formation surrounding the borehole. Fluid is not circulated in the borehole during the logging, thus the fluid sitting idle in the well has more time for thermal equilibration. The mean surface temperature estimate used ( 35 Deg. F for the Cook Inlet Area) is known to be historical data (Dec 77). Since the method is completelY objective and repeatable, it is felt that it provides the most accurate basis for temperature correction available. Minor variation , ten degrees or less, in the surface temperature used for these calculation has very little effect on the salinity concentration. Resisti vi ty measurements reported on the electric log for Lewis River 0-1 includes two separate readings. One is from the spherically focused log. It has a comparatively shallow depth of investigation (generally less than 2 feet) . The deep induction device records resistivities from much deeper in the formation ( approximately 6 feet) which is thought to be deep enough to be much less affected by invasion of drilling or completion fluids. It is the resistivi ty read from this deep induction device that is used for salinity calculations to minimize any influence of borehole fluids. If there had been deep invasion by drilling fluids, then the deep and shallow resistivity should be the same. Instead, they are substantially different with the deep resistivity reading generally higher from top to base of the logged interval in this well. This indicates that formation fluid salinity deeper in the formation is less than it is near the borehole. Hence, the values we reported are clearly not inflated numbers. The electric log for Lewis River 0-1 also shows that fluids above 1,192' MO and below 1,270' MO are in two distinctively different salinity environments. Had there been commingling, the fluid salinities would have equilibrated and the resistivity for each zone would be the same. This is obviously not the case. Therefore, it is clear that a permeability barrier exists between these two zones. This impermeable interval (1,192' to 1,270' MD) is not the only conf ining layer protecting the freshwater aqui fer. The electric log accompanying the Request for Freshwater Aquifer Exemption, Upper Beluga .~ Formation, Lewis River Field identified as Exhibit One during the public hearing shows there to be multiple confining layers. These are represented by shading in the depth track. Reasonable log analysis indicates that these confining layers range in thickness from under 10 feet to more than 400 feet. It is unreasonable to expect that injected fluids would penetrate over 1,000 cumulative feet of superjacent confining layers (at the very least) and eventually mix with the near-surface freshwater aquifer if integrity of the cement bond adjacent to the wellbore is ensured. The Sterling, Beluga and Tyonek Formations each have a distinctive lithologic character that is recognizable from well to well. The Lewis River 0-1 well and Pretty Creek Unit #2, only six miles to the south, bear a strong lithologic similarity to each other. Based on this similarity, it would be very surprising if the fluid chemistry within each formation were substantially different of this short distance. This is significant because a laboratory analysis (Attachment C)· of produced Beluga formation water is available from the Pretty Creek Unit #2 well. This analysis documents a total dissolved solids content, independent of log analysis above 5,000 ppm. This would seem to be reasonable corroboration that the salinities calculated form Lewis River 0-1 log analysis are valid. CONCLUSIONS The submitted data demonstrates that: The general area is not now developed and should not be expected to be developed at anytime in the future because: It is wetland. It is a State Game Refuge. Any development which might occur would not utilize the aquifer for which exemption is sought since good quality water is readily available at shallower depths. That aquifers below 2300' do not currently serve as a source of drinking water and cannot now and will not in the future serve as a source of drinking water because: Under conditions above noted, the aquifers are at a depth and location which makes the recovery of water for drinking purposes both economically and technologically impractical. The water is highly minerialized with total dissolved solids exceeding 3000 mg/l and can not be reasonably expected to supply a public water system, particularly under the circumstances above noted. 1/20/89 1n~of~ Environmental Engineer 0009n <--.----- ;,;.~ 13 _. Unocal Olt &. Gas DivIsion UNOCAle ALASKA DISTRICT Western Region T T1 tNHf!~RHATlGN DATE SCA!.f 163;Wr; CO-NìOIJ-"A$ 'DRAf1!NG I flU. NO A ~---- .---' :~; ATTACHMENT B Geologic Support Information for Lewis River 0-1 Injection Permit Application Prepared by Roger B. Stickney (December 6, 1988) The following discussion presents geologic evidence to show that utilizing multiple sands in the Lewis River 0-1 well for water disposal will NOT cause contamination of freshwater aquifers. ".~;" :,,:". " : : :..~ The relative positions of wells in Lewis River Field are shown on the accompanying index map (Exhibit 1). D-l is the northernmost well and is located approximately 3,000' northeast of the nearest other well (C-I). Lewis River 0-1 is an excellent candidate to use for water disposal because testing has shown that it does not contain commercial gas and there are several sands suitable f.or .injection which a~e well-isolated from freshwater aquifers. In the absence of reliable laboratory water analysis data, electric logs provil.ie the means to· discriminate between fresh\'Jater sands and those that contain saltwater. Because the total dissolved solids (TDS) content (salinity) of fresh water is relatively low, it is a poor electrolyte that exhibits high resistivity~ Conversely, if the water is more saline, it conducts electricity better and its resistivity is lower~ Within the shallowest logged interval at Lewis River Field, high resistivity values recorded on the electric logs indicate that these sands contain fresh water. Focusing attention on Lewis River 0-1 (Exhibit 4&1 -- see Docket), the base of this zone (characterized by resistivities well over 100 ohm-m) occurs at a depth of 1,192' MD where it is underlain by a layer of interbedded siltstone and coal over 70' thick. Below I, 270' MD, resisti v i ties i!"': the porous sands ç¡enerally do not exceed 25 ohm-m, a stark contrast to the interval mentioned above. The difference between these two dramatically different salinity environments leaves no doubt that the intervening layer of siltstone and coal is a very effective permeability barrier. Using standard log analysis techniques, the equivalent salinity of formation water (in PDm NaCl) can be estimated in two ways. One is the Rwa method and the other is the SP method. Both techniques were utilized here and the results are detailed and explained under Methodology (Exhibit 4.3). These methods generally underestimate the actual salinity of formation fluid. Of the two, it is felt that the Rwa method yields the more reliable results because the SP method requires some assumDtions that do not strictly apply to the Beluga Formation. Even with these imDerfect assumptions, the salinity values determined with both methods do corroborate each other in showing that :';, the sands below 1,270' MD 'contain very salty water (cf. Tables I and 2). J) --<1\. ·Y j -~ The results of the Rwa method are presented in Table 1 and also on the 10;.' ( Exhibi t 4.1· -- see pocket) . They show that the equi valen t salinities art; generally between 4,600 and 11,000 PPffi NaCl~·:- Because the Rwa method often tends to underestimate salinity, thè true values are probably higher yet. The key point is that this salinity range is several· times greater than the SOD ppm limit for potability under 18 ACe 70.020 which effectively rules out these sands as being reasonably expected to sUDPly a public water system~ As explained earlier (it is also evident from the accompanying log - Exhibit 4.1 -- in pocket), a freshwater (L)~JÌfer over 1,000' thick lies immediately beneath the surface in the Lewis f\.;ver Field area~ Numerous lakes and ponds there show that the water table remains at or near the surface all year long~ Although Lewis River Field is currently remote from even small population centers, fresh water in this aquifer could be easily tapped by shallow wells should the need ever arise. With continuous re~harge from precipitation and snow-melt runoff, this supply of fresh water is virtually limitless~ Thus, it would be economically impractical to attempt recovery of drinking water from the underlying saltwater sands. Their depth and the high cost of desalinization would render such an uperation economically unfeasible. Water disposal into the deeper saltwater sands woula have no affect on potable water quality available at· Lewis River Field. Using the mudlog, together with" avaj 1 able electric logs and core data, the confining layers· were identified and they are depicted in Exhibit 4.1 (the D-1 log - in pocket) by shading in the deDth track. The main sê.nds targeted for injection in this well occur within the uDDer half of the Beluga Formation. They are isolated, not only from each other, but the shallowest injectable zone (at 2,562' MD) is iSQlated from the near-surface fr:,'shwater aquifer by over 1,000 cumulative vertical feet of impe~ne~ble strata~ The specific zones recommended for injection, are indicated below: Planned Injection Zones (MD) 2,5ó2' - 2,596' 2,850' - 2,900' 2,950' - 2,960' 3,020' - 3,046' 3,714' - 3,768' 3,873' - 3,893' 3,92.7' - 3,918' Total: Footage 341 50' 10' 261 54' 20' 11' 20~ ~;omments Correl. sd 3801 dee52r in C-l. Correlœ zone absent in C-l. Tested wet in D-1 & absent in C-l. Correlo zone very slty in C-I. Tested very subcommercialin C-l. T8sted wet in 0-1 & no gas in C-l. Te~ted wet in 0-1 & no pas in C-l. A correlation section (Exhibit 4.2 in pocket) shows· the stratigraphic relationship be"...¥.Ieen Lewis River D-l and C-l, the n~arest well, locatec' 3 J ODD' to the southwest. The top of the Beluga is represented as a horizont2: datum and the vertical scale is in hundrecs of feet subsea (55). Proposed injection zones in D-1 are plotted along the left side of the depth track. Test data for both wells is also shown. 2~ "__c The generalized dipmeter data~ . which appears on the cross section; attests to significant structural co~lexity between the two wells. The opposing dips .~ are consistent with. the presence of a structural axis between them: .;.--,' Indications are also strmg that each well is cut by a different fault~ Although the quality available seismic data is not good~ our latest interpretation shows that Lewis River C-l and 0-1 are situated in separate fault blocks: With these observations in mind, there are two key points: First, the geologic structure between these wells appears to be much more complicated than the simplistic stratigraphic correlation section (Exhibit 4.2 -- in pocket) portrays. Secondly~ the zones targeted for injection in 0-1 are not in fluid communication with sands in C-l that are capable of commercial gas production. There is good evidence to show that the various fine-grained facies within the B·.luga Formation are impermeable, even when they are of limited thickness. DSTs were cond.Jcted on several sands between 2,868 and 4,980' MD: Although none were found to contain commercial gas~ sands that did test some gas are as little as 40 feet deeper than others that tested no gas~ These results demonstrate that in this area, the sand-deficient, m5-xed lithologies between the tested zones do act as effective confining layers: STRATIGRAPHY Glacial: .....,:,;~:.. ;.'"J The glacial veneer is characterized by a very poorly sorted mixture of pebbles, cobbles, sand and interstitial clay~ Plant debris in various stages of coalification is· also prevalent a At ~'allow depths~ these diverse lithologies tend to be extremely unconsolidated and clay layers are generally discontinuous over large areas. This allows fresh surface runoff to percolate downward unobstructed. As a result, the electric log signatures normally ascribed to the glacial cover include ve~y high resistivity and a featureless sPCXìtaneous potential curve~ Very slow acoustic travel time is also typical . of such noncompacted sediments ~ In Lewis River 0-1, the thickness of glacial veneer is uncertain~ The Sterling Formation that often underlies the Glacial is so similar as to be indistinguishable from it. sterlinq Fm: The lithologic description of the Glacial can also apply to parts of the Sterling Formation. These two units may even be transitional in Dlaces, altha~gh a fluvial origin for the Sterling Formation is well-documented (Hayes, 1976). The resulting· deposits generally include fining-upYfard sequences of bedload conglomerates over lain by thick and blocky quartz-rich sands which are often capped by point-bar siltstones and mudstones. Coals are common and represent the vegetative cover of abanooned meanders. Lateral continuity of these lithologies can be quite good in places. These fluvial sediments have been subjected to effective winnowing and abrasion processes that are together responsible for excellent porosity development. 3. " .:~) In the Sterling Formation, the resistivity curve often shows a Dlock; character due to the contrast between the generally resistive sandstone beds and the more conductive, finer-grained interbeds. These lithologies are similarly reflected en the spontaneous potential and acoustic curves which often makes bed boundaries very distinctive. Unfortunately, in the Lewis River 0-1 well, this is not the case. Here, noncompaction limits log resolution such that the contact between the Glacial and the Sterling Formation, if logged, is masked. Under these conditions, fresh connate water can easily saturate the extremely porous, shallow strata (above 1,192' MD) creating the high resistivity response and a lack of usable character on the spontaneous potential curve. Although proprietary seismic indicates that the Sterling Formation is represented in the Lewis River 0-1 well, a clear-cut contact with the overlying Glacial is not recognizable from available logs~ Quite possibly it was penetrated above the logged interval. Whether or not this is true, their cumulative t.tÜckness is approximately 1,910' and both units Uìdoubtedly contain freshwater sands to a depth of 1,192' MD. A preoccupation with re13tive thicknesses of Glacial and Sterling Formation is of little importanc8. The overriding concern is that the shallow~ freshwater zarle(s), however subdivided, will renain Uîcontaminated by the proposed injec~ion program and the above evidence clear~¥ shows this to be true. Beluoa Fm: , ~:.' Within the Beluga Formation, sands are thinner and more lenticular than in the overlying units. They tend to be encased in low-perm~ability siltstones and mudstones as well as being associated with coals of varying thickness. These are the typical interchannel deposits of braided streams from which the Beluga Formation is interpreted to have originated (Hayes, 1976). Thin, low-porosity stringers occur throughout the section which are probably artifacts of diagenetic cementation. At the higher energy levels which are characteristic of braided streams, finer particles úO not have the opportunity to settle out of suspension. Consequently, th~ resulting sediments tend to be poorly sorted. The "dirty" nature of the Beluga Formation, coupled with the occurrence of hard streaks and coals makes the proposed zones an especially favorable target for injection because permeability should be very low in the finer-grained facies. In Lewis River Field, there is also a coarser conglomeratic facies within the Beluga Formation. These beds have lower porosity than the finer-grained interbeds. The degree to which they are cemented controls the,ir effectiveness as permeability barriers. Compared to the overlying Sterling Formation, log responses are usually qui te dissimilar. The alternation between thin sandstones, mudstone, hard streaks and coal creates an irregular resistivity response. Wi th the predominance of finer-grained facies, the spontaneous potential is also "ragged" and is frequently of little help in delineating bed boundaries. A "ratty" acoustic log response is usually very characteristic of the Beluga Formation. This effect is blurred in the Lewis River 0-1 well, presumably by a combination of noncompaction and possibly transitional lithology at the contact with the Sterling Formation. .-,;'} ;J 4. '- .--) The entire Beluga Formation is approximately 4, 08¿' thick. All of the sands that will be utilized for injection (except as ~ last resort) are within its UDper half. Below 3,950' MD, within the lower half of the Beluga Formation, multiple sands were tested and some even produced subcommercial gas. However. test rates and especially pressures are well below what could ever be considered commercial even under the most optimistic market conditions. Log analysis indicates that other sands below those that were tested also have very minor gas saturation. Since it would be possible to safely utilize any of these sands for water disposal without jeopardizing potential gas recovery, it may be prudent to do so in some cas~s. This would help ensure the availabili ty of sufficient cumulative injection interval in the event that some of the proposed target sands fail to take fluid as well as we hope. At the low rates and pressures we intend to use for water disposal, even under the most pessimistic conditions, the radius of injection around the 0-1 wellbore will be very shallow J even after 15 years, as substantiated by the engineering calculations in Exhibit 8. Tyonek Fm: Although the Tyonek Formation was penetrated by the Lewis River D-l well, it is considerably deeper than a~y of the proposed injection targets. Thus, its description is not relevant to this application. References: .....~ :~:¡ Hayes, J. B., et al., 1976 Contrasts Between Braided and Meandering stream Deposits, Beluga and Sterling Formations (Tertiary), Cook I~let, Alaska: in Alaska Geological S~ciety Symposium Proceedings, p. JI-J27. Hilchie, D. W., 1978, Applied Openhole Log Intefpretati~~: Douglas W. Hilchie, Inc., Golden, CO. Merkel, R. H., Well Log Formation Evaluation: AAPG Continuing Education Course Note Se~ies #14, 82 p. Regulations, Jan 83, Alaska Administrative Code, Register 84, Title 18, Chapter 70, P. 16.5. Regulations, Apr 86, Alaska Administrative Code, Register 97, Title 20, Chapter 25, p. 31. Schlumberger, 1978, Log Interpretation Charts: Schlumberger Ltd., 83 P. , 1988, Log Interpr~tation P:inciples/APplications, 2nd Edition, Schlumberger Educational Services, 198 Po , 1988, Log Interpretation Charts: Schlumbe:fger Educational Services, 150 P. , 1989, Log Interpretation Charts: Schlumberger Educational ServicE-s, 150 p. J RBS/Dg 26640 5. '-. ..-.) -~ ..- EXHIBIT 4.1 Electric Log for Lewis River 0-1 Well (in pocket) '.'"\ '::j ]} ,-,/ .:J) :;) (in pocket) Correlation Section EXHIBIT 4.2 ~J -~ '. EXHIBIT 4.3 ,-=-/ . .. .'') Methodology for Calculating Salinity from Log Data Rwa tJethod: This technique is based on the following relationships: .'<\.'., ·01 Rwa = Rt/F~ where F = O.621¢2.l5 (Humble formula) Rwa Apparent formation fluid resistivity Rt True formation fluid resistivity F Formation resistivity factor ø Porosity Fer a given sand, if porosity, formation temperature (Tfm) and apparent fluid resistivity are known, it is possible to estimate equivalent salinity (in ppm NaCI). It is assumed that NaCl is the dominant salt where specific knowledge of the~actua~'fluid chemistry is unavailable~ Resistivity, read from the deep induction curve (Ri.ld)', . is assumed to be the best approximation of true resistivity of the formation beyond the zone that was invaded by drilling fluids at the time of logging. The formation resistivity factor. eliminates the effect of the rock itself from the resistivity measurement so that the resulting value (Rwa) represents only the contained fluid: Rwe values, when carrected to formation temperature, can be used to es timate sa1~nity with a standard nomograph (Exhibit 4.4; Sch1umberger, 1978). A straight line through any value for Rwa (on the right stem) and the corresponding formation temperature (on the left stem) will intersect the equivalent salinity (on the middle stem). Since determination of salinity this' way involves an exponential of porosity (see Humble formula above) ~ a' small error in poros! ty is reflected as a much larger error in the calculated salinity. In Lewis River 0-1, an acoustic log provides the only available formation porosity data a~ove 2,395' MD. In shallow sediments that have never be2n deeply buried, there is only minimal compaction due to normal overburden stress. Under such conditions, acoustic logs grossly overestimate porosity. Adjustment of these abnormally high porosity values for noncompaction is done empirically and is, at bestt rather subjective. Hence, the results must be utilized with utmost caution. ·Lacking confidence in the porosity data for the zones shallower than 2,395' MD in the 0-1 well, it was felt that calculated salinities would not be valid and are not shown here. ~ (~) -:) ...<~. y "-- EXHIBIT 4.3 (continued) Below 2,395' MD~ a neutron-density log was run which provides more reliable porosi ty da ta since noncomoaction effects are much less dramatic with this tool comoared to the acoustic device. Therefore, density porosity <ØO) was used in the Humble equation. Because salinity is also a function of temperature, Rwa must be first be corrected to formation temperature (Tfm) in order to obtain the corresponding salinity~ Formation temperatures were determined as shown below and they are represented on the log (Exhibit 4.1) at the appropriate depths. Estimated Mean Surface Temp (MST): 350 F (for Cook Inlet area) Maximum recorded Temo (Tmax) from FOC: 1350 F @ 8,025' TMD (-7889), i.e., 7,989' BGL where BGl = Below Ground Level Thermal Gradient (TG): TG = (Tmax - MST)/(Depth BGl/IOQ) = (135° F - 35° F)/(7,989'/lOO) = 1.252° F/IOO' It is felt that salinity estimation with this method is most valid, so this technique was used for selected sands below 2,500' MD. The results appear on the log (Exhibit 4.1 - see pocket) and also in Table 1 along with the parameters from which they were calculated. Sc:ne sands in this well contain small amounts of gas, yet test results show that even the most prospective ones are subcommercial. The presence of even minor gas is emohasized because it causes Rwa to aooear abnormally high. This must not be ignored because it will result in salinity estimates that are artifically low. SP Method: This is a well-known aporoach which involves calculation of formation fluid resistivity (Rw) using the spontaneous potential (SP) curve from the elect~ic log. In general terms, in a given sand having even a small amount of permeability, the character of the SP curve will reflect the degree of salinity contrast between the drilling mud and the fluid in the formation. EXHIBIT 4.3 (continued) ~r :"~ Under ideal" conditions, using corresponding salinity) can work utilized very cautiously because To g=t reliable results, a sand following criteria: . 1) It needs to be sufficiently thick to allow the SP curve to respond to its fullest extent. This maximum excursion of the SP is called static SP or SSP. The minimum thickness required for this to occur is approximately 30 feet~ the SP curve to determine Rw (and the Quite well. Most often~ however, it must be several factors can suppress SP development. within the zone of interest should meet the 2) It should also because these developnent. be "clean", lithologies i~e., devoid of mudstone or shale interspersed with sand limit SP 3) The sand should be 100% water-wet since hydrocarbons can also suppress the SP curve to an unpredictable extent. ") According to the mudlog and the electric log. sui te J sands of the Beluga Formation in Lewis River D-l (between 1,934' and 6,020' MO), contain signi ficant amounts of muds tone. This mas t C8 :-tainly limits SP response. Referring to the depths shown in Table 1, most, if not all of those sands fall short of the ideal criteria listed above. Th·~¡·efore, others with better SP character were chosen for analysis. As was poir:~,=:d out above, certain sðnds do have minor, sLtlcommercial gas saturation which also likely contributes to an SP which is less than the ideal SSP. Several references describe how Rw can be calculated from the SP curve and there are often minor disparities between the various recommended techniques. U$ually these differences can be ascribed to the way a particular log analyst chooses to correct for less than ideal condi tioîls in the forma tion he is anålyzing. The service company charts used in this analysis are included herewith as Exhibits 3 through 6. The Schlumberger charts were chosen because they allow the user to make some corrections that are frequently ignored by other general purpose charts. They also circumv8nt other inappropriate assumptions. Table 2 d~tails the raw data and the values used from each chart. -' Gen-9 R (ohm-m) 1'01 t£ {"02 .03 t04 .05 rOG .08 to.! I~ I l2 -r.3 I~ .... :t e:: +.4 +.5 1'- :';) t·G .;.J t''::' I +,8 r·o f~ :t ~ c:: 1: It~8 =-4 t .. -r~ -J-6 + Ì~o I~ ± ..:::.. 2 0 a. (f) © Schlumberger 1:!50 .8 -:t 40 .6 I 30 ·<ì 20 .3 j: .2 100 Exhibit 4.4 or Rz = R (T ,+ 21.5 ) lor' °c 12 + 21.5 ' (TI+6.77) .oF RZ=R T2+6.77 (Arpa)' ·Conversion appro xima t ad by: i -~) 500 400 300 250 ,X\... J 10 8 ì 500 6 400 300 4 3 200 2 kppm gIg " @ 75°F 300tl7500 200 I?>OOO J:: 10000 I 00 :j: :~t:t¡ggg :3000 40 30 2000 20 1000 40 ~ O 20 °C 10 ,-~) .- RESlSTIVIToy NOMOGRAPH FOR NaCI"'SOLUTIONS I I tf~ì·1E. ~í~~ SPOSTA~EOt:S rOTE~~L·\l r -~_. .~. ----- ---- '-"- ..) '1~~ff~!t:~~~1~{~~I~r,t~~j~~~~~;~~~~1!~~f~;~t~~~~tl~~ :'~:.:. :;"~: ;. :.'\<:::~~I '. .' . I.' ~I~-bh '. ".~~ ...~S ·\.o~~~---ki~':" ',: ,:' :.. ~.~:<,,,~~:., ~~'- '- 10... : - ~~ !.1~ I oe _ I l'... "\.J""-.,,,", 'oe " ~ '\ '\.,'\. Ì'-..:>.,1 : :-.' . ..' '. ......._~. o,e ...... oe "'- pi \.--'\.~,\I~} '- - 'I\.\ \. 5 -'. .. ..:~,-;::(~ ~.~..~;~t...., "20' '.~r'-:. " ~"'~", ~.2,- :'--.- \ 1'\ '\. ~,,\'2 '\ ',... '\.i \ i\ ;~\J "-.-:.:.~ .tX:;~.i:~,~..~f.;-;~r;;¿~:-:·~' '\ \ \ '\ . ~':- : ;~ 'f~ .-- '\ '*'" ~~ '\, ?t· \ \. '\ \ \'5 '\ Y¡;;" - - ~ \ \ \ "\ \ : -~z Š'6 .~~..,..._.. _. ''1.I'-':''''~ 0 6 .~.":")' "-·0 8~ ''\..5 - ~ 0_8 \ T '\ ~ i\ .,,08 \ \ \ \ .,.-...., ~). ~.......;..'-a1~~!,,~~~~:š'..:~. '.' \ \ ::..;.::~.~~.. I' \'-\. ','\ ...,~ .~'..>..'. I ' ,~-~,._. 120 :::...~~..~ ~ ".J."'::';';":~"f:!":.-;.~7J '.'~ \ .,~: 'j:.:~~.:':'-. \ . \ \ , ' '. .:~.. ' .'.l.- :-,,':~..c:::;,,:,. ._.t.-.-...Io¥.....~.~. \ \ ... _...:-",....'~. ~~ '~t-.... ~\\I\·\·_· I \~\\.,...-,.~. .".. - 1\:........, ¡¡¡... SO ..... '\ 1.'01 .' 1\ 2?\ ',.,.' ,,' ·I'~ ;.f?~rW!f~iì{~/' '\: ~ ~ :::{s~ô' =-~' '~\~:~'::O:' _.~ ,,~«\ \~~:4 I ~ ~ ~ SO, ~~)~{~_ .;;.~,..:.;~.T.;..~~.,.......\~' I '- 100 ~. ("~':'. . -·11l'-'\ \1\~SJ' ,..... '\.. I SO .~...... -;--j I\. ·"00\ 'J~...:i.;', _. . ....,...._ .... .... " ',. '" '- ~_~o '\ ,'- 'I . '~~ '-.-'- ':-::.~:.::_.~:~'.__'.:;. 0,2 200 . .'.' _ 0,2 -. -," ..,-~.....'{~~ 02 I I I ..... 1~ I· 0.2 ~ I --r';'11~2Od' ..'~:.-' . "":,"~'¡:, . ....,.~ li" I ...... SO'. : ! "-. ~ - - - I ...::. :--;.;,.;:!\.~.~.~~7.~~..;t,,~. R.JR,.../j:<,....:. I IIA,.IR,.:·(I00""l,.....·.-... I IIA.JA..~j;·,~;:' IIA.JA..V:o:,-·..:·~· .. ..".._-,(,...:t."'~' "..._;;....-,- . ...., ' L ."'''' -:"'"...... _.~; ''<- ~.....;,:.. ., '.:...;'~" .; '40 30 20 15 '0 7~ 5 ~- ....:. - ~ 40 30 20 15 "0 7 5 5 '.::- 40 30 20'5 '0 U 6 .~.'t.: 40 30 - 20 '5 . 10 1.5 5 t ',:-'~.'~ '- ~ß;~;¡,~;!~&t~;±1;~.:¡~,:'<h(~Ú~~:::ti::.¡)~ªf¡\-g:!:;: :~~~~;~l~::~;: i.:;i£~;;~~;;E:ð¡féÒS 5~~¥~ /~~ ~~; ;;':;'::;i~i10;h~?;. '. .~~ ~,. K.''''' 5 .:-1.0t-., 2~ .' .. .. .., ·1.0 -. -. I . I . 1.0,=-c ~ 5 ~ -;.~ . ~ 1 ;.........:- ;~:/;;.-;:~ ..~.~. .....: ~ r--.... Ij~-5, : ..,,". ~~~: .:~.:, ~~--~i'" :--~;. ~~~~ :.~_:~.:~;>. ...;...~:.... Rm.r.....;._;"',:'.;.. .r-",t-""{ - .J_... ,....-';l- ~~--........¿~- -- - -' .2_ .... .- -; -I ~:::....~~ '..:;'...: r'\. - ........1'" 5 ~;:'''..'''' '::::~..}~~:;~:;X:~i.i~;:'¿.::· ~t'...... ì I '10 .:.~::_..... '-"I' Œ.5 ~'~-8 _ ._. ~ ._i _~ ':;:'0~1 '\. I '\{ ~'\ ·:r·::~ .:_.._~;~~:::;}o.:.=...yoe~r-~ T' I .:...:...~._.C'8-' --N =-...;: . I I . 5 -:.': 1\ ~I\ 1"0 "':". £¥~~~£~;~:;~~~2:: - _r..... ,I" ~ :::}~L,~"~. '>.:-~. ~.. . ~'"" ~.:;:.: " I ~ . " .~~:":, -~\ I'\. \, ' ~::.-"'..'" --:,w:.':."ul:I'~~~I\:~:;.'';'~'. r \ \. '- ,~:..::::.... '\. - :~.,;,.. 1\ \ 1\ ì'\ 'to ,,':-:-00 \1 \] Ì\ 'r 20 .-~::"::-;., ~....",...",~...._.r'(¡~06 ,'\ ,- ".'" \. 2- '·06 i\, 1\ '06 I'\"'~ '.., ~~.;;~~~~·~~{:1t;~;~fJ.( \ \ '\ ~50 "·~·~·~0"+~:~ '\ '\. ¡~. "--,,,1'1 " _.~_: \I\J. 1\ \J '20\ ~'.;.t· 1\ [\ \1 \1 \ ~~~>t' .:';:=;~.:~..i':~1?IC'~;';;,~~ {:,~ 'II \ ':~,·i~Ä.':'·i'~'t'",,* I -~I*'--~I'-s :r;'J \ li\ II \1\ \ 'I_~::':~\l 1\ ~\ .~.~:'~; '._..._.~'''''' ~..,.." ¡¡¡:. . '\J....... ~S': I '\. . '\.. I .. · I\. i \.1 ..- . r--+--'l- r '. -_.~_.þ- ~~:~7:~~-fÔ0~~'~'~- '\" 'tOO .:~'-+~;:~'~ "~m' ~ )~.~ \\ Ì\ 1\ I'so .:~O: I I\I\J -so\ :~~:~~}- ~~~1Ü&~:i::3:; I '\ N -'~:}~n} I S :--r~ ~:;Y I )\..1 ~1~ '{L~: I l"\.. l"t~ ~~ijJt:: ..;;~~~.~~:~g&.~;",~~~ " . 200 .~:~'~~~~~:.~.2 ---1'· -'. : ~~' ./.~.2¡ I I 'I' ;:;:;~~ I ~,. ¡ 2001 ::){~~i:' ..~Y';-"'.:r.:;~r:'."~~<"~.:...,.... :. 1'-......1 .:~.~-'/ :":~.'.:: I I'-......N· '- I . .::...~'=' I.......... 2OO.p :.J; r¡.- I 500" ,\".:1.:.......,<. ~";;"~:;:;i")...~~:1'~~;;)r~:'-: 500 "';:f".,::;;;'·j 'I ~100 ":;·:.;1 I II I ~-. ;."'~:;:; RIO':"" '1 .,;';.::-::'-' .....-..._;,."'?-~'o:!O........~I.~.. R.IA...- ...._..r... I R.A 200 . ~~~ A.oIf1,.. - 500 ."" .o""" I -.--J ,.".-...--.., 111~~~~~l~!~i~il~]~&~¿~~~~t~&~~~\!!~;~~?Æ~§r¡'~f.~~;i~~f~l '_=.... .&,._ 20,~_-... ....... 'I ....._ "'1-...~1 '5~ '~~"~.'.'" ~- I I '._. Io.-.....;..-----~·- ,-¿'_I ~-,.,. ~ s... .~..'~"--' ..-.-.' Rn;.... ...·.......1 "-! 1.......1 ~....... ~_,_-l'.-t-.....~ 1----'-- ..~'~. roo.... ~ ....... ~...,.. n;:> ..'- ji~~;1;!f~~~t~ '- I"-.J'L N.:°'f}~~'~;~~ ~ "1:~:::f~.~Ì'-.~ Ì'<ì--.J 5, y~:; ~ N"'-. I ì-~' :if.!E ;,~~Ð:~~;!f:t~{;'."f.;~ ",,\I·'\¡ I 20, \;;,~;:¡;, "l 'i.. ~ .... ,J ',- ':F: "l '\¡. ~ N 'O'r:;1;~: \J !\, 1\ Ì'\ I '\ Em~t :..!.' .... ,,_.......-..: ,I.. ..'..~..- '\:I i\:-- ~ ...-:.:.- .~",. .... " 1 'I 'i.' 5 I ..~. I \ I \T "'l' "'. ;. ~ 1\ \J \j \. ..' . ~ . ~TÆt~#iif~l'~~:~ \ '~ \-t \0 ;;~;;£f2f \1\ 't'\ì '\ " .'(~. \j T Î" ì\J ~,iF;~ \1 \ ì \ ì\ '\W't'z ;~;;i.~{'8¡~%~~:' \ 1\ I 1'\ f ':,.' .:~~:~~ 1\ ~ 1\-1""" ~;~, f\ 1\1, \ l'so :¡rt 1\ 1\ I \J )\00 :}i~~¡i f.:J*"~~;::';iŒ:~J... LU..~:4 \ '-: I '\ 100 ~::~~~-:~::.......0_4_ I 'I..... 1...... 20- :::~.4" ~ "I ~ \ ~i~~:'~' " I \ \.\- 111_~ '~~;.;~;.. ~1~'.~-. ~ ,.,.'_.',.... ¡",.., ..... ""'r,h~~-,.....L....· '-.... ." ".0-'" r-···· 'l I'\. '\J '\. ,.......--,-. !....:Jo."J,:::. ,(¿;~.::.-.f~..::..f:.~... r, . '- !" ·.";....~:.:W.:.~;' ..... ". ,- ;,~:;. . .1';,;-. :'::;~',:: ~~._=~.:,__-....-..:.;.~. "- ~ '\... I ..~...,........,:, ~ ." '\J. =.".,. '" '\, T":J 100 I··..··~·· I'\{ '\l i', :-~.or.-.~:. ~1t~~~~ì} ì~'N:~~~~E~ "~~~':'1~~ ,'l'~:~~ I I~"~::~~ ..-tlB;:~~~~!f.:~;:: I I I~. J ::::~.z.}:¥~., I ~S ;:;~~: I· ~500_j:j£; \. I --,,000 .:;~~~~.~~ ...!J......t.:.-.-...-:-..-"....-.. R.1R...-+-í1OOO .-;:-. .,_.,~- R.JR.."f" f""^'i :---". R..,JR...+-·pooo ~.. R..JR.,.-+-- . ~-~_.. 1!'I~t~t~i~i~lfJÆlr#~~Er~;~I!t~!!~?i~~;iff~\1;~¿~~iilfJ: 'f.~5i!:( .En!~~ abscissa·."ith:;;.aJue of hid. (raiiq. of bOdßuckriêšS to hole dianieter):';;X"~~~ifI:~:t:l'S:5}:pX:·r··· <i<''''}}Ê~f~ +)g:5::~;~~,{-:..Go·.veitically ··up tc{ curvé for appi-öpnåtè· R/Rm (for: riQ in,:åsion) or_ RxcIP·~· (for mVaded cisés); interPolating .~;:~~2~~~, SP Correction Charts (FOR REPRESENTATIVE CASES) /:-~~ J S J Q J ~,) :j 3 iJ J ..J ,~ ~ i ~ ì i 11 E r h ~~~ ... s"o"""~r0l'''; I'OTES11'\l _..~J -....... . .....-.~ "'."," ----~ ~!' ~,...t_ ..~') Rweq Deterlnination frOil1 EssP (CLEAN FORMATIONS) ~~.:~~:'::_~.h"': ;-:. ..ø¿{..... .·~~:~.t;:~·~~~·~~~:::~~~?~·:;.:.:¡;:~:~i~..:~r~·~~ ...:~:.:._."* ..... ~.~_~.~:.~. "0 ~~:·-.:.i:_1 .;"~"'~.'~_~~'<.'~".:'."-~''''''''''':'-:-':''_-':' .'.r.: "0" ,0., :', ':'.,:~"~:':~'.' This chart and riomoir~'\ph. calculate the equivalent formation water resistivity, R1o\eQ' from the static spontaneous ~.~:::\·.:i~:' potential, Ess~~ 'measurement in clean formations. .. .. " . :.......: ::. ..' . '. . .,. .- .." . .~;,::.~~.;>.i Enter the nomogr'apti\"ith E¿s~ in mY turning through the reservoir temperature in OF or °C to define the . I>.~~:·.< Rmr~(~1o\tq ratió.: .~r.om !~i~ v~I~:, p~ss ~hrough t~e. Rn1rtQ \'~Iuc to define R1o\t( . ;;':'.:::' >.:.. - For ·predomir1a'nil)' ·NaCI mûds determine Rmrrq as follows:.: . ..:.;.::,~~~:-:.~.. :.... å. IfR~'ràt75°F(24°C)isgrcaterthanO.1 r.°m, correct Rmrtoformationtcmperalure ':':;.:.'..': :~.._ ".. . -' .. '...: .'. ......,.~ '. . _ _ ~....,;,.-:.'" :':.:.':. :. .;.;.... usmg Chart Gcn-9, and use RmrtQ = 0.85 Rmro·, ..':.. .. ..' , '. .. . .'~' .'. ..' . .. ... _.' ·~·:~,,:·~-,··,-.:.::"·".:7','.-"" ...4'):",:'^.L.......,_...¡.'" ....-... .... ..-;- '._ 'q. - ~-'-: -.-:-r·" :..-...-.... .. .~~-_.................... :.._...~.:. .._:~...:...-...~~.... ".\ . >.:_;'.~.. ::-:':~:.'::,;.\~'::__: b". If R~""-at ï5°F (24°C) is less than 0,1 n'm, use Chart SP-2 to derive a value -........ '-.' ':.., ···.......:........._1 ~ 0" 0. t"'..·:--;·..--...-...-·........ . 0, . ..._".-..... .' ......~...._....... . :....". 0.. .::. ~.~. .~_ ..:....... of R~rtq at formation temperature. . '.; . ,. . .'.:.....,. . ·~.~~..::.::·;:,.·'...~.-.XA..:-...~,·.·.:.~lft~._.:j..TSR';.Sm~?-1~0·í.~7ÓO.¡'o·~·~~vm···~@·t;21500(ìO~F·~:··o:;·r~·0;°.'33 ~~m @. ..')50° F.·"" _... _ : ....'..; . .~. E~s~~:-·K~-.J~~ R~ir<:~ . ' :' ·::·2?:~·)~i:f1;~~Ì11·¿'ic ro;e:~~'r;q = 0.85 x 0.33 = 0·.~8 !)'m @ 250°F. . . .' ,;;;.~ ~~~ ¿I: J:i~; ~:; . . ':;~i:~.::\fJr{2~,,;~~~:.~;f~~ .?~~~ 2~0.: F: :., . .. .u: ':' .~:-... .,. c" " ¿~ ¿;'~ 0.24T-c ) . ~t ~ '.. Rmleq·:- '. '. Oom . . ':: . :~..::~. . I :~.~1.;. . ': " . .02 . ... . ~ 1-.04 :t.06 0+- l-r·~ .2 .£ I f.4 ..±. _ 6 1: 14 I I6 -10 + ¡20 140 ..Í- teo - . -=-'0-0 . .'. . .4 .6. .8 2 '- 4 0 r.,- - 6 ~ w 8 10 20 :~ _#f ... ..",.'. ," C SChlumberper Sp·1 Rw&q nom .001 . . . ¡"-- .-' .:... ;:~;: to.1 2.0 8 E X h ~ f~ f t 4 .005 .01 .02 .05 0.2 0.5 '.0 . . ~~ ..j ~ .." '.'. F.:' ~ ~ ~ E- E: ~: ~ ~ ~ ~ ... ~; . . - ~ þØ. ~ ,....~ ~ ~ ~ ~ ;,.. ~ þ'- .... --, þC. þ.. - . ~ -- ~ ¡O' , 11 ... - .¡ ..:.:. - - .¡IIA --.. . - ~.;- .;:- . --_: _. . i.-. --¡ -. - -- ..î. "'_.1 1 - r-" . .. ;~~ SPONTANEOL'S POTENTIAL Rw versus Rweq and Formation Temperature .- ~. ....~;..,...Lt,s...»'J~J~~~~.¡..a.~~-":'.....,.-...,.,,'(\..*..-.~~......."IIf.r"'"":"""-'~.....fI,.'......-"w4..,...,. -"",,-.,... ~-.: ... ...;'::-- -.. ~ ..' . _. ..4... .." . . .'.' '". . .'..o::....~... .U!:'.V~"'-t. .~.~_\ .;'~_~--"~»~_~A__~'~""'. ."....-.y.i~~n~"h·..;.,.~·~t.,..~~""!.¡¡...~· ..... '.. ."::1 )0. ~- ~. ... . '. .".: . 't:'~ :-ç.~~' o~~. t. 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';è;¡;.~"'-,... mf7d!' . ~~. - ~~ ··W~~*'-.,;,¡~·,-~;;.:--~¥·,..to~~~······ -[~~~~~¡_íi~~15i~~¡I!ff~!t~i~_~if)l · :¿;;~These cl:tar~ convertlequi\'a1enfwater·rèšistivitY~R~;··from cnaii SP~l ìôãèiûJài wàièr;iêS~Viif·R:'¡-Th·èÿ~1i~~§~ .:~:t~? ~Š~.€.ü.sêcf t~.è~~~e!t~~:tó:·~:¡~ì;:{~ifri~~üds~~~~~:~~~~}~i~¡;~.t(~~;;~~.f,1~~~~~~~~;.;{~~~~~~r~~~~j ·k:~.Y¿~.E!Æ:~º!~?.!!É.~ fo.~pr~ªriij¡í~¡!i!"aèr.;y!lt~~~ÌlásÍîê4i¡~es:i~~rixfii:~¡éfui~~~~~)t{¿~~ ---~ lion waters·· (wher· _e' fr ts';ll\: fsalts'';''f.; h· '.-.ï:T';;"""'-Cl ~::·-r:.-'-··'\fi· -,.. ..... . ,....'r...._...~·.-::"...-......$·J..~_..- ........,... . .~~_,...4~... :~:;:z~__~&õ:.~""~. ~ . ...~.".r;~ ~. 0,..." .ot 5r U.l~.1~~._ ~lI!e slgru)~nt).-.The d~hed portiori~ 'rØå'Y-ãlsõ'bêûsed for :::;.r,;,~~¿i; ~~~~ ~-~.~ .ad·~··--~ç~~:--·~: ,..:;~...-".-:':";"".";\' ~~\'\:'J'-~.~:<::'~:'-+"'i''t~=t~-:;:;'''! ~~.'f,,,(;.~;:r .~;~~.. . ._.. . ·.·~~!:';"'-::';''('#-:~~::ioili'~~-~·I contInue on next e,¡ ,!,~::.~., _ _ .... %.>:'" ._ .'"'_' "'~'~.'. ,...-_.....,>-"' ~.-"l' .",--..-_.j!T;-;:.:;( <~... '.. -OJ ........~ ..."",--.."", '!:?!'ii'l''''' ....,-. .,='"'q".~'. .'~.- .. .pag , .;."" . ......"., !f!tf.«.!;t.t.~.;.B..· h Ev i 9 ) þ .......)... .~. ., .... ~ 1 j ~ ~ ~ .. J .J J J .( I :1 :t it II I r - J 1 J J - ~ -'....,_...-' ~'" Table 1· ~) . . Deoth Dens~ Equivalent MD SS B:.1- Tfm Poros. Rt Rwa Salinity (ft) (ft) (ft) (DeQ F) (%) (ohm-m) (ohm-m) (porn NaCl) - 2576 2451 2551 66.9 25 12 0.98 6,500 2590 2465 2565 67.1 24 13 0.98 6,500 2853 2728 2828 70.4 20 16 0.81 7,500 2878 2753 2853 70.7 18 14 0.57 11,000 2892 2767 2867 70.9 19 17 0.77 8,000 2955 2830 2930 71.7 22 20 1.24 4,600 3024 2899 2999 72.5 16 25 0.78 7,500 3038 2913 3013 72.7 14 25 0.59 10,050 314 32 33~).s 3456 78.3 17 20 0.71 7,800 3ï17 3591 3691 81~2 15 21 0.57 9,400 3740 3614 3714 81.4 17 18 0.64 8,500 3758 3632 3732 81.7 19 17 0.77 7,000 3885 3759 3859 83.3 15 25 0.68 7,600 3912 3786 3886 83.6 16 28 0.88 5,800 MD MeasÜred Depth SS Subsea Depth BGL Below Ground Level .'J Tfm Formation. Temperature Rt True Resistivity Rwa Apçarent Fonnation Fluid Salinity RBS/PQ 26630 .) ..... L ..:.::..,...:. ~' ~~. ;: "} ..-:"..J . . '. ( TABLE 2 Meas Depth ( ft) Parameters from Rtn 3 Rm Rmf Hole Tfm Ð Tfm ø Tfm h SP Qt?~ of °C (ohm-m) (ohm-m) (ft) (mv) Rs/Rm (lr,) SP / SSP h/dh Rxo/Rm SPcorr (mv) Rmfeq Rweq Rweq Rw Rmfeq/ G Tfm ~ Tfm G75°F ~ 75°F Rwfeq (ohm-m) (ohm-m) (ohm-m) (ohm-m) Equiv NaCl Û 75°F (ppm) 2590 67 19 2.10 1.11 24 -10 4.76 14 1.71 4.76 0.58 -17 1.65 0.94 0.55 0.50 0.50 11,800 2895 71 22 1.99 1.06 30 -10 6.03 16+ 1.88 6.03 0.56 -18 1.75 0.90 0.51 0.49 0.49 12.000 3100 74 23 1.91 1.02 35 -12 21.47 13 2.69 21.47 0.43 -28 2.41 0.87 0.35 0.35 0.35 17,000 3365 77 25 1.85 0.98 38 -10 26.49 12.5 3.04 26.49 0.45 -22 2..00 0.83 0.41 0.42 0.42 14,000 4455 91 33 1.58 0.84 32 -10 9.49 13 2.46 9.49 0.41 -24 2.20 0.71 0.31 0.37 0.37 16,000 Tfm Formation temperature (see log) ( Rm Mud resistivity (see log header) Rmf Mud filtrate resistivity (see log header) h Bed thickness SP Spontaneous potential Rs Shallow formation resistivity Dh Hole diameter Rxo Resistivity of flushed zone (lacking a micro1og it is assumed that Rs = Rxo) SPcorr SP correction (see Exhibit 4.5) SSP Static SP (see Exhibit 4.5) Rmfeq Equivalent mud filtrate resistivity where NaCl is the dominant salt (Rmfeq = 0.85 Rmf since Rmf a 7SQ F 0.1 ohm-m; Schlumberger. 1987) Rweq Equivalent formation water resistivity where NaCl is the dominant salt (see Exhibit 4.6) Rw Resistivity of virgin formation fluid (see Exhibit 4.7) RBS/pg 26680 C· ---. ATTACHMENT C ..-' 5633 6 STREET ANCHORAGE. ALt..St<A 99~,e T=~=PHONE (907) 562·23~3 FEDERAL TAX ID . 9¿~~OI..(~ CHEl..flC4.L & GEOLOGIC4L L4BOR4IORIES OF AUSK4., L\YC. AnI-IS!S t£POR! t! ~,.ÞŒ'I.[ ior Werk C'Ider , 7!U Dati ~Iport Prln\td: JU~ 1S 8E t 12:S3 Cllent S4Dpl. ID:PRr::I CREEr - PROD~:tD Wk:tR P~'S! D : Colllcted JU): 6 88 ( hu. r..lcl1ud JU)i 6 88 (09:4S h:r. PII.elTed w1th :HO~t Cllen~ ~ð~ : U~a:ÀL Cllent Àcct : UNO:ÀLP P.O.I nUlL r...<\ I O:ò'Ied By : fRtD DU!~1ILtR kn¿lY111 CoÞpl.t,d :JU~ 1~ 86 LaboIðlcry SUP~01 :S;tP~ C. rDt f,tllalld Cf: / . ~ 5u\d P.eportl to: l)UHO:AL 2)ftED DU!HWtILtt·UNOCÀL-PRODU:!ION ...........---.....-...---..--------..-.---.--.-------._--.~.-...._--_._--.-...----------_.._------------..-----.-----....---------- Sptc1~1 AL!Et~k!t CO~!ÀC!: JOHN tt¡!IA 263-7672. Instruct: Cr.enlab Ref 1: 1323 Lab SIt?l ID: 3 )(a~:1X: \iater Pa:alleter luted Reu.:.lt/Uni t¡ Me~hod Allowable Limits ----------------------------_.~--------------------------------------------------------------------------------- ( 1CP-2S tLD!~}'" SCAN rJa rJa 1CP \ U trY.::! )..1J}( HDeO.OS) nç/l !!'"þ ... !F.sr:.::c HDeO.OS) nç/l l'"þ ... til,I'aY. 1. 3 xzç/l I "Þ ... FO?,O~ E.3 zr:; / 1 IC? CJ..1.CIU){ 120 IÞ;/1 1"0 '-. C¡.DYJUY. 0.12 rrç/l 1"0 '-. CSO}I.JID! k1>(O.OS) 1Þ;/1 1"0 '-. COPPER C.10 nz; " 1:P , . IRO)\ {70 nç/l ¡ CP LHD 0.12 r,,- /' !:p "':J. .. )I). ~ K:: S I UY. s: :,;/1 1::' VJ. ¡;:;hhE S:: 3.5 ~/l ....0 l,-. Y.;:?:U?.! KD(C!.OS) nt;/~ T"O . '-. J\¡ Cr.!!. 0.51 rr.;/l 1"0 PECSP~OP.œs 0.S6 nç/l PC:!SSIUX 73 rÞ;/1 ""0 .t ... S!1.r}i~uy' J\D(O.OS) IÞ;/~ ::P SILICO}: 15 nr;/1 1"0 '-. S n.vIR k~(O.OS) nz; ,. !:p 1_ SODn)}! 1~40 rÞ;!1 ::p S:r.OK'ZIUY. C.~5 ~n : :p :1); ;.0 ~;/: I :P VUlLIUH )iD(0.05) ::¡;/: I:P Z IIi: 0.72 nr;/i ""'0 ,¡ ... 7. H.:O}i~ID! k"D(O.OS) =;/~ !:p RO~!K! "'·J.7EP, HH~SlS rJa rJa CE.0:.1Dt 21.20 n.;!l str.: 1.:E ~.D rÐ;/1 F.!SiDill:: (7DS) fU7!F,AtLt 5220 þ;/l K.i.:.DKL SS (as C!:03) S~2 ~/l J.L!J.:!h:;~ '.. ~ : ') ESO n:; 11 ( ..- ,..--- 563~ B STREET ANCHORAGE. I..LJ..SKJ.. 99515 TELEPHONE (907) 562·23~3 FEOERJ..L TAX 10 ~ g2·0040~~O CHE.\I/C4L & GEOLOGIC4L L4.BOR.4.TORlES OF .41ASK4., lKA~!SIS REPORT BY SÀ~t[ for ~ork Order. 7111 Date ~tport PrInted: JUK IS 86 t 12:~4 Clltnt SaRpl, ID:PRr:7T c~trt - PtODU:tD WÅ7tt P~!D : Collected JU~ 6 88 t h:a. t,celTed JUH 6 88 (09:45 h:I. P:e"rved wIth :WO~E Cllent· ~6~ : U~O:ÀL Cllent Àeet : UWO:ÀLP r . ú _. Vtf.t1L F..q I OIó.rel ~y fttD DL~HW!IttR !nalYEII Conpletld :JU~ 14 88 tabolalC:r Supe:~HE~ C~tDE t.eluud by : )0.... / ~I ~ S,nd J\epoltl to: 1 )m:O:H 2)fRtD DD:W~!!Ltt·ONO:kt-P~ODUC:IOH ......---.......-..-..--.-----.--......---------.................---.....-....------..----....------...--.........................-- Spee1tl l~!EtHÀ!t COh1ÀC!: JOh~ t!~:IÅ 263-7672. In!au::t: Chen1~b Ref t: 1323 Lab Sr;?l ID: 3 Ka~:lx: Wet.: Pa:a~eter Telted tuuh/U~tl He~hod 111 ow able LiJ:lU ( ---------------------------------------------------------------~----------------------------------------------- COKDU:!IVIT! pH 7690 w.."",o./er: 4 . 6 ur.:. tI Se.:::?H te::¿:;a: .......-..........-.......................---........................------.....-----.----..........--........ ( 3~ :es~1 FI:!o:~d ~T'· ~on. De~ec~ed ^k· net !~ly:eè See Spe:~al !~::\::::::ns lDon .. See S~I:jÜ. terœ.:r.. l.tlon Li·Lert ¡nan, Gi·~:.~:e: ¡~n Ui.· ü:\e. va.:.la:'l e #7 TRUSTEES FOR ALAS~h \~ PUBLIC TESTIHONY O?; UNOCAL'S APPLICATION FOR AN AQUIFER EXEMPTION AND AN U.NPJ;:RQ}~OUNJ2_ _ ;r}I J:E.C.T);O~___CON.TBº_~ {tiT ÇL._p ERHIJ~_ FOR ~EWI ~__I<-IVER WELL D-l J..A~JJ ðJ~Y_ 1 3 ,__1.2 8 8 I. Aquifer Exemption application comments. REêEI.VED JAN 1 8198Q Al~!~.~j.~:~ Gas.ConSeß.ommlSSIOII ~¡~..jÆ; AnchpraøQ~.$~·,¡.;''''c.,>-", A. Legal, A¿~inistrative and Procedural Comments. 1. UNOCÞ.L has not applieè for permi ts fro!"!"· the Alaska Department of Environmental Conservation which appear to be required for this activity and would have direct be3rinq on the is~uance or denia] of an aquifer exemption: a. A waste water disposal per~it appears to be required pursuant to 18 AAC 72.210 which requires a permit for the disposal of nondomestic \A7astewater. "Nondomestic wastewater" is defined as "liquid or Hater-carried wastes resulting from a manufacturing... or production enterprise; industrial esta~lishrnent; development or natural resources; ... or other wastes which are waterborne or in a liquid state." 18 AAC 72.990. It has been our experience in other ADEC regions in Alaska that applications for UIC permits and aquifer exemptions are filed concurrently with ADEC waste water disposal permit applications. This was not done in this case. 1 1 .. ...---~ .- b. A solid was te disposal permi t may be required if solids are to separated froD the fluids and disposed of separately. It is known that a reserve pit existing at the D-l well site was closed out in 1981. If UNOCAL anticipates reentry or reuse of this .t- pl _, this should be indicated ·in the applica tion. If UNOCAL will be handling API separator bottoms or other listed wastes at this facility, then the procedures for hazardous waste under RCRA may be required. 2. UNOCAL and/or AOGCC have apparently failed to notify the Office of Management and Budget, Department of Governmental Coordination of this application so that DGC can render 1) a federal consistency determination under 16 U.S.C. 1456, and 2) a "conclus'ive state consistency determination" as required by AS 44.19.145(a) (11) whenever an application requires permits, leases or authorizations from two or more government agencies. This permi t cannot be granted until such determinations are made. 3. Section 307(c) (3) of the Coastal Zone Hanagement Act of i 1972, as amended by 16 use 1456(c) (3), requires a certification that activi ty affecting land or water uses in the Coastal Zone complies with the Alaska Coastal Management Program. A deter- rnination of consistency with the Matanuska - Susitna Borough Coastal Management Program is also required pursuant to AS 46.40.010. UNOCAL or AOGCC had apparently failed to notify the Matanuska- RECEIVED 2 1 JAN 1 81989 ~~.ml.& Gas Cons. C.OmmissJon ~"""I~ ra__L____ --- --" Sesitna Borough or the Office of Management and Budget. Division of Governmental Coordination of the proposed injection well acti vi ty', and as a resul t, has failed to receive a determination of consistency. The proposed activity is within the Mat-Su coastal zone as shown on Tyonek Map #89 of the ?laskan Coastal Zone Boundaries (attached). 4« Ci ti.es Service Company f a predecessor corporation. to UNOCAL, apparently had a fill permit from the Army Corp Of Engineers for the D-l pad but UNOCAL has fai.led to transfer the fill permit for the Lewis River D-l pad from Cities Service to UNOCAL. UNOCAL must aþply for and recei ve a transfer of this permi t before an Aquifer Exemption or a DIC perrrit can be issued. 5. Public Notice issues. a. Manner of publication. AOGCC's October 7, 1985 application for primary enforcement responsibility requires AOGCC to allow "any interested person" to be heard at any hearing. However, the public notice published by AOGCC for this perrr:i t limi ted the opportuni ty to protest and request a public hearing to those "person [s] who may be har::-¡ed if the requested order is issued." This language unlawfully restricts public access. By discouraging public participation rather than encouraging it, this perDit application notice violates both State and Federal law. b. Language describing the agency action.REGEIVED 3 JAN 1819R9 Alaska on & Gas Cons.a CommisSion ""~¡"~i-~ ~chQragø ; '---' Actions taken by the Alaska oil and Gas Commission are l"n +h 1.... e for rr~ of "orders" rather than "~ permll-S. althouah permits are specifically referred to in the federal and S+--.+r-. \".CI. \".C statutes and regulations, "Oràers" being a direction of a court, they are inappropriate fer AOGee when ADGCC is acting as an administrative body. The "orders" do not list spscific requirements for compliance as permits would. This is a violation of the intent, if not the legal requirements, of the UIe program. c. Time periods allowed for public comments. When administered by the EPA prior to June 19, 1986, the UIe program required a 30-day public notice period for comments and/or requests for public hearing. When primary enforcement responsibility was granted to AOGCe in June of 1986, public notice periods were reduced to 15 days. Reduction of the public comment period in this manner severely i~pacts the ability of the public to participate in the permitting process in a state the size of Alaska with its geographical i~mensity and impediments to communication. It may also violate guidelines found in EPA f s Guidance for State Submissions Under Section 1425 of the Safe Drinking Water Act, which requires notice that is "adequate to bring the matter to the attention of interested parties and, in particular, the public in the area of the proposed injection." Id. at Section 5.6(e). Residents of remote sections of the state such as those adjacent to the Lewis River Field may never become aware of these actions prior to the expiration of the public comment period. In 4: "-",,," the specific case of the Lewis River permit request, it is doubtful that the residents of Tyonek village, the Grants area, the Susitna Flats area, application or the Alexander area have been informed of this or have been provided a reasonable opportuni ty to comment. AOGCC should renotice this application for an additional 15 days and make a concerted effort to provide notice to, and solicit comments from, those citizens who would be most affected by this action. 6. Procedural Issues. a. There is no defined procedure for applying for an aquifer exe~ption. Thus, deter~ination of the progress toward issuance or denial of an application cannot be determined by reference to the materials in the public record. For example, if AOGCC or EPA were to deter~ine that the application lacked technical documentation, interested parties such as Trustees for Ala&ka or the Alaska Center for the Environment would have no way of knowing that such information had been requested or was available for review. Procedures should be revised and forms devised to provide for a rational and trackable perITitting process. Forms and procedures should, at a minimum, incorporate the following: (1). A standardized application form detailing the information that must be provided by the applicant before the application can be considered complete. (2). A formal determination of application completeness by AOGCC and/or EPA and a notification to the applicant, and the 5 '-" public, of this dete~mination. Conversely, if an application is found to be inco~plete, ~his should also be formally conveyed to the applicant and interested T'I~""'~~~t:: 1:"'----'--, in 't'-:ri ting along wi th a definition of what additional materials are required to complete the application. (3). Issuance of a draft per-TI:itíexemption by EPA/AOGCC and public notice of this action f along wi th a request for public comment on the draft perrrit. (4) . Issuance of a fact sheet accompanying the draft permit/exemption describing the proposed project to assist members of the public in under-standing the project and the issues. (4). Formal written guidelines for evaluation of an Aquifer Exemption by the EPA/AOGCC staff. (5). Proper public notice in accordance with Alaska Statutes and EPÞ. guidelines ,. '.' SO.....1.Cl.t:lng comment on the permi t/exemption application. (6). A proper format to include responses to public comment in the permit/exemption record. (7). Proper public notice in accordance with Alaska Statutes and EPA regulations of final EPJ.../AOGCC action on the requested permit/exemption including procedures to appeal the action. (8) . A permit/exemption form which would be issued to the successful applicant detailing his entitlements, limitations, monitoring requirements, and reporting requirements. 7. The land on which the Lewis River D-l well will be drilled 6 ----- is not included in the Lewis River Unit. AOGCC's authority under AS 31.05.027 and 180(p) to issue aquifer exemptions for activity outside of an existing oil and gas unit is highly questionable. Moreover, neither oil nor gas was found at Lewis River in com~ercial quantities. and well D-1 was plugged and abandoned on October 3, 1981. The lease on this land will expire after 10 years pursuant to AS 38.05.180(m), and, we believe, will expire in the next year or two. Since an oil and gas lease cannot be extended "unless oil or gas is produced in paying quantities," this underground injection permit cannot be granted for a period of more than a year or two. These issues must be resolved prior to the issuance of an aquifer exemption on this land. 8. Some of the injection fluids listed by UNOCAL pursuant to 20 AAC 25.252 (c) (7) are ineligible for -disposal into Class II wells. EPA has provided specific guidance on the fluids eligible for disposal into Class II wells, 40 C.F.R. 146.5(b), and these do not include such fluids as equipment washwater or other liquids not brought to the surface in conjunction with oil and gas production. 9. UNOCAL has failed to demonstrate that the aquifers below 1300 feet below ground level contain more than 3000 parts per million total dissolved solids. Such proof must be provided by a sample of the formation fluids analyzed in accordance with 40 CFR 136 using method 209 B (attached). 7 '-~ 10. Tte Governor's office is reauired to adopt a wellhead protection program pursuant to Section 1428 of the Safe Drinking Water Act. This prograr must be in effect by June 19, 1989 and will protect "the surface and subsurface area surrounding a water well or wel2.field." Since the applicant has stated that there is "a freshwater â~uifer over 1,000 I thick [which] lies immediately beneath the surface in the Lewis River Field area," the size of the aquifer is unknown, this exemption should not be granted until the studies required by Section 1428 are completed. Otherwise, the public ~ay be foreclosed from ever using this known fresh water aquifer or the aquifer proposed for waste disposal as a drinking water supply or for any other use. 11. Si~ilarly, a demonstration program to protect sole source aquifers must be implemented to protect critical aquifers pursuant to Section 1427 of the Safe Drinking Water Act. Sincè the Matanuska-Susitna Borough, or other state agencies, may identify the aquifers below Lewis River as cri tical aquifers I EPA/AOGCC should not grant this exemption until such time as the other interested "!'!':unicipal or local governments" have had a specific opportunity to comment upon the impact of contamination of these aquifers. B. Aquifer Exemption Technical comments 1. UNOCAL has estimated equivalent salinity in ppm NaCl for 8 I· COASTAL ZONE BOUNDARIES OF ALASKA ---- - - -~--- - --- --------- ------- -- .-_. -- - - -------- ----- --- - -- --_.-- ------ -~-- ~ --------- _ _0_______ .._ ---------~--- M ~ ------- I --- -------.-- o ---=:L.. JUNE 1988 10 16 ::!:,6 MILES 20 r ~ ( 20 ......l,6 KILOMETERS 10 15 Baaed on a USGS map Unlvera.1 Tunaverae Mercator Projection -------- TYONEK #89 ITl I 11 R...'. '...m., .n ... ..w .. -.. .- --... I _ .w ~"'I C4..... ..... ....... .... ... .... INOEX '-..... .-~ Inland Boundary Seaward Boundary --- District Boundary ------- BOUNDARY DESCRIPTION Federal Lands: Excluded from Alaska's coastal zone boundaries are "those lands owned, leased, held in trust or whose use is otherwise by law subject solely to the discretion of the Federal Government, its officers or agents. ." (15 CFR 923.33). Activities on these lands are subject to the consistency provisions of section 307 of the Coastal Zone Management Act of 1972, as amended. Seaward Boundarv: The seaward coastal zone boundary is the "outer limit of the united states territorial sea" (15 CFR 923.32), which is the "three geographical mile line" (43 CFR 3301.1). All offshore waters on this map are within the coastal zone. Ken'!!.i Peninsula Borouqh: The inland coastal zone boundary in the Kenai Peninsula Bort'ugh is the interim coastal zone boundary. The inland boundary west of Cook Inlet in this portion of the Kenai Peninsula Borough includes the lands and waters within: (1) the looo-foot elevation contour south of the Chuitna River, (2) the 400-foot elevation contour. north of the Chuitna River, and (3) other areas as delineated on this map. The inland boundary on the Kenai Peninsula in this portion of the Kenai Peninsula Borough includes all lands and waters. Matanuska-Susitna Borouah: The inland coastal zone bound3.ry in this portion of the Matanus'ca-Susi tna Borot:.gh includes all islands and the lands and waters within: (1) the 400-foot elevation contour near Beluga Lake; (2) the 200-foot elevation contoul east of the Parks Highway; (3) the Skwentna and J<ashwitna rivers and Talachulitna, Sheep, Little Willow, and Willow creeks upstream to the 1000-foot elevation contour, including all lands and waters within the 100-year floodplain or 200 feet bn each side as measured from the ordinary high water mark, whichever is greater (includes all lands encompassed by the extended boundary, such as islands in a braided stream or river, even though they may be higher in elevation than the lOa-year floodplain); and (4) other areas wi thin the borough boundary, township lines, or west of the Parks Highway, as delineðted on this map. Reference to 1:63,360 USGS topographic maps, Federal Emergency Management Agency Flood Insurance Rate maps, or other information which defines the lOa-year floodplain may be necessary to determine if the above criteria apply and whether the use or activity will lie within the coastal zone. ~ªÁ~tv of An~ho~: The inland coastal zone boundary in this portion of the Municipality of Anchorage includes Fire Island and the lands and waters within: (1) a zone extending 1,320 feet inland, measured horizontally, from the extent of the 100-year coastal flood; (2) the lOO-year floodplain or 200 feet from the center (whichever is greater) of each river and stream intersected by the 1,320-foot zone up to the 1000-foot elevation contour; and (3) other areas as delineated on this map. Reference to 1:25,000 USGS topographic maps, Federal Emergency Management Agency Flood Insurance Rate maps, or the Anchorage Coastal Management Program ,may be necessary to determine if the above criteria apply and whether the use or activity will lie within the coastal zone. ,~. the formation fluids adjacent to the D-l well by extrapolating from electric log resistivity data. There are several problems with this approach: a. The fluid parameter that is of concern is TDS (Total dissolved solids), not salinity. different values. b. Total dissolved solids are defined in 40 CFR 146.4 and are determined by EPA method 209 B as listed in 40 CFR 136. A copy of These will be significantly this sample procedure is attached for reference. A formation water sample will be required for this determination in accoràance with 40 CFR 147. c. The resistivity reading may be affected by well completion fluids which may have migrated a long distance from the well bore. d. The temperature gradient calculated by UNOCAL may be incorrect. The 35 degree assu~ption for the surface may be correct for the ambient air temperaturè, but certainly would not-be correct for the subsurface groundwaters. We suspect that these waters would be in the 45-50 degree range at a minimum. 2. UNOCAL's Geologic Data for Freshwater Aquifer Exemption is replete with wording such as: "In the absence of reliable laboratory water analysis data" "assumed to be the best approximation" "when corrected to formation temperature, can be used to estimate" It is quite obvious that this is only an·approximation of -the 9 .. ,-; - ~ aquifer fluid properties. '2 ...J . It does not appear that AOGCC has the legal authority to waive the requirement for a laboratory analysis of a formation water sample. UIe program primacy conveyed under section 1425 of the Safe Drinking Water Act applies to UIe class II permits but does appear to convey the authority to grant aquifer exemptions. It appears that such authority is reserved for the EPA. Item 13 of the signed memorandum of agreement between AOGCC and EPA states that aquifer exemptions will be approved or disapproved by EPA within 14 days of EPA being notified by AOGCe. 4. Item 3.7.f of EPA's guidance for State Submissions Under Section 1425 of the Safe Drinking Water Act states that " At a minimum ¡the memorandum of agreement should: f. provide that aquifer exemptions for Class II wells be consistent wi th aquifer exemptions for the rest of the UIC program;" This makes it quite clear that an aquifer exemption for the Lewis River D-l well must be consistent with an aquifer exemption for a Class I, III, IV, or V well. 5. UNOCAL's assumes that the aquifers below 1300 feet beneath Lewis River well D-l cannot ever be utilized as a drinking water aqui~er'for reasons of economics and practicality. UNOCAL has not presented any proof of this assertion in the form of engineering or economic studies. The burden of such proof rests upon the 10 f -.; ~ -------- applicant. 6.· UNOCAL has not addressed the issue of casing cementing as required by 20 AAC 25.252 {b} . The integrity of the cementing of this well is particularly critical between 1190 feet and 1270 feet of measured depth. Cement bond logs performed on this well begin at approximately 1330 feet. UNOCAL must demonstrate the integrity of the cement between 1330 feet and the surface. 7 . UNOCAL has not specifically identified the confining formation for this well. UNOCAL describes the formations between 1193'and 1270' feet below the surface as a "permeability barrier but do not designate it as the confining formation for the injected fluid. UNOCÞ..L must identify and detail the lithologic characteristics of the confining formations, both upper and lower, before an aquifer exemption or a UIC permit can be issued. 8. Porosi ty for this well is listed by UNOCAL at 18%. Porosity is used as a factor in UNOCAL equations used to derive salinity. The required injection pressure may be 1500 psi and_ the average disposal rate is proposed to be 75 barrels per day. A surface pressure of 1500 psi will result in a downhole pressure of between 2800 and 3000 psi at 3000 feet. A rate of 75 barrels per day is about 2 1/4 gallons per minute. If this formation does indeed have a porosity of 18%, this disposal rite should be capable of entering the formation with little or no surface pressure. The 11 ------- reason for the excessive back pressure must be explained by UNOCAL and how this injection pressure is related to formation porosity and disposal rate.· 9. UNOCAL' s characterization of the aquifers beneath the Lewis River well D-l is incomplete. Additional data needed includes: a. Definition of the aquifer charge/recharge mechanism b. Definition of the aquifer drainage mechanism d. Definition of the movement of fluids through and within the aquifer. II. UIC permit application comments A. Legal, Administrative and Procedural Comments. '1. UNOCAL has not applied for permi ts from the Alaska Department of Environmental conservation which appear to be required for this activity and would have direct bearing on the issuance or denial of a UIC exemption: a. A waste water disposal permit appears to be required pursuant to 18 AAC 72.210 which requires a permit for the disposal of nondomestic wastewater. "Nondomestic wastewater" is defined as "liquid or water-carried wastes resulting from a manufacturing.... or production enterprise; industrial establishment; development or natural resources; ... or other wastes which are waterborne or in 12 i· .~ a liquid state." 18 AJ...C 72. 990 . It has been our experience in other ADEC regions in Alaska that applications for UIC permits and aquifer exemptions are filed concurrently wi th ADEC waste water disposal permit applications. This was not done with this permit. b. A solid waste disposal permi t may be required if solids are to separated fro7 the fluids and disposed of separately. It is known that a reserve pit existing at the D-l well site was closed out in 1981. If UNOCAL anticipates reentry or reuse of this pit, this should be indicated in the application. If èrnOCAL will be handling API separator bottoms or other listed wastes at this facility, then a permit may be required under RCRA. 2. UNOCAL and/or ADGec· has apparently failed to notify the Office of Management and Budget, Department of Govern~ental Coordination of this application so that DGC can renàer 1) a federal consistency determination under 1.6 U.S.C. 1456, and 2) a "conclusive state consistency determination" as required by AS 44.19.145(a)(11) whenever an application requires permits, leases or authorizations from two or more government agencies. This permi t cannot be granted until such determinations are made. 3. Section 307(c) (3) of the Coastal Zone Management Act of 1972, as amended by 16 USC 1456{c) (3), r~quires the applicant to certify that activity affecting land or water uses in the Coastal Zone complies with the Alaska Coastal Management Program. A .deter- mination of consistency wi th the Matanuska - Susi tna Borough Coastal 13 1 -; ·- '-- Management Program is also required pursuant to AS 46.40.010. UNOCAL or AOGCC had apparently failed to·notify the Matanuska- Susitna Borough or the Office of Management and Budget, Division of Governmental Coordination of the proposed injection well activity which, and as a result, has failed to receive a determination of consistency. The proposed activity is within the Mat-Su coastal zone as shown on Tyonek Map #89 of the Alaskan Coastal Zone Boundaries (attached). 4. Ci ties Service Company I a predecessor corporation to UNOCÞ..L, apparently had a fill permit from the Army Corp Of Engineers for the D-l pad but UNOCAL has failed to transfer the fill permit for the Lewis River D-l pad from Cities Service to UNOCAL. UNOCAL must apply for and receive a transfer of this permit before an· Aquifer Exemption or a UIe permit can be issued. 5. Public Notice issues. a. Manner of publication. AOGCC's October 7, 1985 application for primary enforcement responsibility requires AOGCC to allow "any interested person" to be heard at any hearing. However, the public notice published by AOGCC for this permi t limi ted the opportuni ty to protest and request a public hearing to those "person [s] who may be harmed if the requested order is issued." This language ~nlawfully restricts public access. By discouraging public participation rather than 14 . , ;_:F j -; .- encouraging it, this permit application notice violates both State and Federal la~. b. La~guage describing the agency action. Actions taken by the Alaska Oil and Gas Commission are in the form of "orders" rather than permits, although permits are specifically referred to in the federal and state statutes and regulations. "Orders" being a direction of a court, they are inappropriate for AOGCC when AOGCC is acting as an administrative body. The "orders" do not list specific requirements for compliance as permits would. This is a violation of the intent, if not the legal requirements, of the UIe program. c. Time periods allowed for public comments. When administered by the EPA prior to June 19, 1986, the UIe program required a 3D-day public notice period for comments and/or requests for public hearing. When primary enforcement' responsibility was granted to AOGCe in June of 1986, public notice perióds were reduced to 15 days. Reduction of the public comment period in this ~anner severely impacts the ability of the public to participate in the permitting process in a state the size of Alaska with its geographical immensity and impediments to communication It may also violate guidelines found in EPA IS Guidance for State Submission under Section 1425 of the Safe Drinking Wa ter Act, which requires notice tha t is tI adequa te to bring the matter to the attention of interested parties and, in particular, the public in the area of the proposed injection. n rd. at Section 5.6(e). 15 ;, .~' Residents of remote sections of the state such as those adjacent to the Lewis River Field may never become aware of these actions prior to the expiration of the public cornment period. In the specific case of the Lewis River permit request, it is doubtful that the residents of Tyonek village, the Grants area, the Susitna Flats area, or the Alexander area have been informed of this applica tion or have been provided a reasonable opportuni ty to comment. AOGCC should renotice this application for an additional 15 days and make a concerted effort to provide notice to, and solicit comments from, those citizens who would be most affected by this action. 6. Procedural· Issues. a. AOGCC has not established a defined procedure for applying for a UIC permi t. Thus, determination of the progress toward issuance or denial of an application cannot be determined by reference to the materials in the public record. For example, if AOGCC were to determine that the application lacked technical documentation, interested parties such as Trustees for Alaska or the Alaska Center for the Environment would have no way of knowing that such information had been requested or was available for review. AOGCC's procedures should be revised to incorporate forms and procedures to provide for a rational and trackable permitting process. AOGCC' s forms and procedures should, at a minimum, incorporate the following: (1). A standardized application form detailing the information 16 1 c '---- that must be provided by the applicant before the application can be considered complete. (2). A formal determination of application corepleteness by AOGCC and a notification to the applicant, and the public, of this determination. Conversely, if an application is found to be incomplete, this should also be formally conveyed to the applicant and interested parties, in writing along with a definition of what additional materials are required to complete the application. (3). Issuance of a draft permit by AOGCC and public notice of this action, along with a request for public comment on the draft permit. (4). Issuance of a fact sheet accompanying the draft permit describing the proposed project to assist members of the public in understanding the project and the issues. (4) . Formal written guidelines for evaluation of a UIC application by the AOGCC staff. (5). Proper public notice in accordance with Alaska Statutes and EPA guidelines soliciting comment on the permit application. (6). A proper format to include responses to public comment in the permit record. (7). Proper public notice in accordance with Alaska Statutes and EPA guidelines of final AOGCC action on the requested permit including procedures to appeal the action. (8). A permit form which would be issued to the successful applicant detailing his entitlementsr limitations, monitoring requirements, and reporting requirements. 17 \-_--r 1 -, ~~...-""" . -..--' 7. The land on which the Lewis River D-l well will be drilled is not included in the Lewis River Unit. AOGCC's authority under AS 31.05.027 and 180(p) to issue UIe permits for activity outside of an existing oil and gas unit is highly questionable. Moreover, nei ther oil nor gas was found at Lewis River in co~mercial quantities, and well D-l was plugged and abandoned on October 3, 1981. The lease on this land will expire after 10 years pursuant to AS 38.05.180(m), and, we believe, will expire in the next year or two. Since an oil and gas lease cannot be extended "unless oil or gas is produced in paying quantities," this underground injection permit cannot be granted for a period of more than a year or two. These issues must be resolved prior to the issuance of an aquifer exemption on this land. 8. Some of the injection fluids listed by UNOCAL pursuant to 20 AAC 25.252 (c) (7) are ineligible for disposal into Class II wells. EPA has provided specific guidance on the fluids eligible for disposal into Class II wells, 40 C.F.R. 146.5(b), and these do not include such fluids as equipment washwater or othei liquids. not brought to the surface in conjunction with oil and gas production. 9. UNOCAL has failed to demonstrate that the aquifer~ below 1300 feet below ground level contain more than 3000 parts per million total dissolved solids. Such proof must be provided by a 18 10. .r~-": . -c -~~ ~ sample of the formation fluids analyzed in accordance with 40 CFR 136 using method 209 B (attached). 10. The Governor's office is required to adopt a wellhead protection program pursuant to Section 1428 of the Safe Drinking Water Act. This program must be in effect by June 19, 1989 and will protect "the surface and subsurface area surrounding a water well or wellfield." Since the applicant has stated that there is "a freshwater aquifer over 1 ,000' thick [which] lies immediately beneath the surface in the Lewis River Field area," and the size of the aquifer is unknown, this exemption should not be granted until the studies required by Section 1428 are completed. Otherwise, the public may be foreclosed from ever using this known fresh water aquifer or the aquifer proposed for waste disposal as a drinking water supply or for any other use. 11. Similarly, a demonstration program to protect sole' source aquifers must be implemented to protect critical aquifers pursuant to Section 1427 of the Safe Drinking Water Act. Since the Matanuska-Susitna Borough, or other state agencies, may identify the aquifers below Lewis River as critical aquifers, AOGCC should not grant this exemption until such time as the other interested "municipal or local governments" have had a specific opportunity to cömment upon the impact of contamination of these aquifers. 12. UNOCAL apparently has not submitted evidence of a surety 19 -- '~ bond or a financial statement verifying the resources necessary for plugging and abandoning the well. The bond normally posted with AOGCC applies to oil and gas wells or strategraphic test wells, not injection wells. Modification of form 10-402 appears to be required or a separate form developed. 13. AOGCC's systems for a permit transfer appears to require modification for injection wells, e.g. - Application for Sundry Approval form 10-403, Designation of Operator form 10-411, and Notice of Change of Ownership form 10-417 all appear to require revision. B. UIC permit application technical comments 1. UNOCAL has not described those surface facili ties necessary for the processing of the fluids to be injected into well D-l. UNOCAL's application should be revised to describe these facili ties. This will be required for obtaining an ADEC waste water permit 2. The fluids proposed for injection are not adequately characterized. For example I workover fluids such as acids and bases are not characterized. 3. UNOCAL has not described the manifesting system which will be employed to trace these fluids from the point of origin to the point of disposal. 20 1 .~ ~-.~'" -...,.,.... 4. UNOCAL has not described any contingency plans or emergency plans for controll·ing well proþleres or surface facility problems such as spills. 5. It appears that this well will have a substantial capability for backflowing. A surface safety valve will be required at a minimum. A sub surface safety valve may be required to protect drinking water formations from a backflow of injected fluids and hydrocarbons from the injection zones in the event of well damage between the surface and the injection intervals. 6. UNOCAL has not described its plan for conducting !>1echanical Integrity Tests on this well. 7. UNOCAL has not presented any information concerning the current condition of the well. After seven years, this well may not be worth attempting reentry on. 8. UNOCAL has not described its stimulation plan for this well. 9. UNOCAL has failed to demonstrate that the fluids proposed for injection will be compatible wi th the receiving formations fluids and lithology. 21 '~.......... '- 10. UNOCAL's calculation of the extent of radial invasion is inadequate. The calculation addresses only one interval whereas UNOCAL is proposing injection into one or more of 7 different intervals. 11. UNOCAL has not addressed in sufficient detail the following items, among othersr pertaining to the processing of the fluids proposed for disposal: a. Transport of the fluids; b. A thorough description of the sources of the fluids; c. On site storage and processing of the fluids; d. Metering of the fluids; and e. Record keeping requirements for these fluids. 12. UNOCAL has not addressed in sufficient detail the follow- ing items, among others, pertaining to the physical appurtenances of the injection well and to its physical integrity: a. Well head safety systems; b. Subsurface safety systems; c. Annulus monitoring and vacuum/pressure safety devices and alarms; d. Tubing pressure moni toring and vaculU!'l/pressure safety devices and alarms; and e. Workover plans tQ ensure the physical integri ty of the well. 22 c_ c,~ 13. Trustee's takes specific issue with UNOCAL's request for a waiver of the require~ent of 20 AAC 25.252(e). This well has been suspended/abando~ed fo~ 7 years and may have serious structural inteqrity problers. The present condition of the casing, tubing, and cement related to this well is unknown and waivers of those requirements designed to ensure the integrity inappropriate. The small thermal gradients that would be experienced by this well should result in minimal thermally induced pressure effects in the annulus. A pressure rise of 200 PSI in the annulus of this well would be indicative of a potentially serious problem. of the well are 14. UNOCAL's application does not address a water well which is at the edge of the Lewis River D-l well pad. It is unknown if this well penetrates the proposed injection zone. 15. UNOCAL has not addressed the disposal of solids that may be filtered out or settle in tanks at the well head. This would nor~ally be addressed by a separate solid waste disposal permit application to the ADEC. 16. UNOCAL's application for a Underground Injection Control permit does not appear to have been certified to be true and correct by a responsible corporate officer. 17. UNOCAL has not submitted a plugging and abandonment plan 23 - ~.....________..J for well D-l. 18. UNOCAL hás not submitted evidence of a surety bond or a financial state~e~t verifying the resources necessary for plugging and abandoning the well. The bond normally posted wi th AOGCC applies to oil and gas well or stratigraphic test wells f not injection wells. 24 \ ' 'i .. § 136,3 40 CFR Ch. J (7..1-87 Edition) Environmer TABLE 1 B-LrST OF ApPROVED INORGANIC TEST PROCEDUREs-Continued TJ Reference (met'Y.>-d No. or paga) EPA 1979 Parameter, l Para~er, UMS, and method 04;:.'7'" USGS I ~ 51. PIa!r.1...--n--Total', mg/L: Digestions . I I. i followed by: . I I tric, 1SO'C. I . 55. Residue-non1itterabJe, (TSS), mg/L: 160.2.............. 209C............. ~.........._....... 1-3765-84 .......... Gravimetric. 103-105'C post washing of residue. 56. ResidlJe-settJea.ble, mg/L: VoIumet- 160.5.............. 209E............. ·............._.......11.......................... ric, (Imhoff cone) or gravimetric. . I c, 57. Residue-Volatile. mg/L: GraVlme- 160.4.............\ ~D.............I................__....·...11-37.3-84 .......... tric. 550'C. 61. ;:~~t~~~~ï.:;·O.·4·Š..~~~~··¡ 270.3·..........·..1303E ............·1 03859-84(04)......1'-3667-84 .......... filtrabon Io/;owed by: ¡ I i _~ I I 319B.1e 200.7.~ 33.107.' 200.7.4 64. Specific conductance, micromhos/! 120.1..............1205............... D1125-82(A¡__...I,1-1780-S4 ..........1 33.002.' em at 2S'C: Wheatstone bridge ! . . I 65. ~~:~~.e a(:. SO~~~;~tric. (barium' 375.1..............1........................1....................._...1.............................. chloranilate) ~ i I ¡ ~~:=tric~::::::::::::::::::::::::::::::::::::::::: ;;;:~::::::::::::::I·.~~~..~..~~.·~:::I g;~ ~;~~¡ ::==::1 ::::::::::::::::::::.:::::::::¡ ~~.;.: 66. Sulfide (as SI m-,)/L: i I I ¡ ! 67. ~:~:%:~~~~:;~~~S:=~~::¡ ~~+:::::::::J ~~~~:::::::::::+6~~;:~:=¡~=V~~.~~~~;:::::::::J 228.4.'0 (Iodine-iodate). . .. I I I. I I 68{me~~;:~ta~~:. mg/L ColonmetriC 425.1.............15128.............1 02330-82(A)_..¡.............................. 69. Temperature. . C.: Thermometric .......... 170.1..............1 212 ...............1......................_..1.............................. Note 31. 70. Thallium-Tot followed by: AA direct asp; AJ1. furnace, 0 Indu..rtively CO' 71. Tin-Total', lowed by: AA direct aspi AA furnace,... 72. Trtanium-Tot tollowed by: AA direct asp¡ AA furnace .... 73. Turbidity, NTU 74. Vanadium. Tot followed by: AA direct aspi AA furnace .... Inductively co: Colorimetric « 75. Ziflc-Total s, lowed by: AA direct asp! AA furnace .... Inductively COt Colorimetric (( (Zineofl)........... 200.74 1 "Methods for ' Geological Survey, 2 "Official Methe , For the detem solubilize suspend "Methods for Cher less vigorous dìgE cautioned that. thí~ employed, it is ne<: situations, the vigc containing large Ii technique, ìnductiv mercury, selenium. specific instructiOn NOTE: If the dig, be used. Dissolved metal' filtration of the.san be omitted for AA the following crneri a. has a low COI b. is visibly trans C. is colortess wi d. is ot one liquit ~ The full text c Analysis of Water ¡ ~ Manual distill at this preliminary di~ 6 Ammonia. Aut( AüíoAhalyzer n, Te 7 The approved Sediments", USGS 8 American Nati( New York. NY 100 · "Selected Anal the Fifteenth Editio 10 The use of no 1 1 Carbonaceous "tota! BOD." The . parameter. A disci procedure tor repo report data using tt 256 § 146.4 :~:, I··· ....~... . ~..,'..- -? -j.~. . ,- ~3~·'~ ..... .~;~;.~ -::- ;:~_::- f, SDWA means the Safe Drinking \Vater Act (Pub. L. 95-523, as amended by Pub. L. 95-190. 42 U.S.C. 300(0 et seq. ). Site means the land or water area where any facility or activity is phj-'s- ically located or cOI;1ducted, including adjacent land used in connection with the facility or acti\-ity. Sole or principal source acquifer means an aquifer which has been des- ignated by the Administrator pursuant to section 1424 (a) or (e) of the SDWA. State Director means the chief ad- ministrative officer of any State or interstate agency operating an ap- proved program, or the delegated rep- resentative of the State Director. If re- sponsibility is divided among two or- more State or interstate agencies, "State Director" means the chief ad- ministrative officer of the State or interstate agency authorized to per- form the particular procedure or func- tion to which reference is made. Stratum (plural strata) mearlS a single sedimentary bed or layer, re- gardless of thicIL11ess, that consists of generally the same kind of rock mate- ria1. Subsidence means the lowering of the natural land surface in response to: Earth movements; lowering of fluid pressure; remm'al of underlying sup- porting material by mining or solution of solids, either artificially or from natural causes; compaction due to wet- ting (Hydro compaction); oxidation of organic matter in soils; or added load on the land surface. Surface casing means the first string of well casing to be installed in the wel1. Total dissolved solids ("TDS") means the total dissolved (filterable) solids as determined by use of the method specified in 40 CFR Part 136. UIC means the Underground Injec- tion Control program under Part C of the Safe Drinking Water Act, includ- ing an "approved program." Underground injection means a "we]} injection," Underground source of drinking water (USD\V) means an aquifer or its portion: (1)(i) Which supplies any public water system; or 40 CFR Ch, I (7-1-87 Edit~} (ii) Which contains a suffir,-.... quantity of ground water to sup;::~'-;, pu blic water system; and (A) Currently supplies driri--· water for human consumption; or .-.... (B) Contains fewer than 10,000 mg ¡ total dissolved solids; and (2) Which is not an exempted aq:.L fer. USD W means "underground SO:lrCl" of drinking water." Well means a bored, drilled or drÜfn shaft, or a dug hole, whose depth Í,<; greater than the largest surface di· mension. Well injection means the subsurfa...^f' emplacement of fluids through a bored, drilled or driven well; or through a dug well, where the de-pth of the dug well is greater than the largest surface dimension. Well plug means a watertight and gastight seal installed in a boreholE- or well to prevent movement of fluifu. Well stimulation means several p!'oc- esses used to clean the well bore. en· large channels, and increase pore space in the interval to be inje<::teà thus making it possible for wastewater to move more readily into the forma· tion, and includes (1) surging, (21 jet- ting, (3) blasting, (4) acidizing, (5; hy- draulic fracturing. Well monitoring means the meas-Jre- ment, by on-site instruInents or l:::.bo- ratory methods, of the quality of water in a well. (Clean Water Act. Safe Drinking WatEr Act Clean Air Act, Resource Conservatior fend Recovery Act: 42 U.S.C.6905, 6912, 6925 6927,6974) . [45 FR 42500. June 24, 1980. as amendfd at 46 FR 43161. Aug. 27, 1981; 47 FR 4998. Pt-b 3, 1982; 48 FR 14293, Apr. 1, 1983] Invironme (l)Itisr thermal e: demonstra part of a p n or III OJ or hydr0C2 Quantity a be commeJ (2) It is tlon whic] for drinki callY or tet (3) It i wöuld be cally impr tit for hur (4) It is mining ar catastropl (c) The of the gro and less tJ reasonabl: water syst (Clean Wat Clean Air Recovery i 6927, 6974) (45 FR 425 47 FR 499f I. 1983J § 146.5 CI Injectio lows: (a) Clas tors of ·h operators ment fac waste be· tion con- . (lM mile +____ ground_SJ i (2) OU t disposal neath tt ¡ taining, , well bor drinking (b) Cl fluids: (1) Wh in conne natural commin~ gas plan of produ waters f waste at . I I I i I t f ~ § 146.4 Criteria for exempted aquifers.. An aquifer or a portion thErE-of which meets thé criteria for an ··un- derground source of drinking wa~er" in § 146.3 may be determined under 40 CPR 144,8 to be an "exempted aqui- fer" if it meets the following criter\:.. (a) It does not currently serve ES a source of drinking watcl·; and (b) It cannot now and will not in the future serve as a source of drinkim: water because: 662 93-1 92 ROSEN. A.A. 1970. Report of research committee on tastes and odors. J. Amer. Warer Works Ass. 62:59. SUFFET. I.H. & S. SEGALL. 1971. Detecting taste and odor in drinking water. J. Amo. Water Works Ass. 63:605. GELDARD. F.A. 1972. The Human Senses. John Wiley & Sons, New York. N.Y. PHYSICAL EXAMINATION (201 STAHL, W.H., ed. 1973. Compilation of Odor ar Taste Threshold Values Data. Amer. So Testing & Materials Data Ser. DS 48. Ph; adelphia, Pa. AMERICA."i SocIETY FOR TESTING AND MATJ RIALS. 1973. Annual Book of ASTM Stane ards. Part 23, D-1292-65. ASTh Philadelphia, Pa. 208 OXYGEN TRANSFER* - A standard for the measurement of oxygen tranSfer in clean water has been adopted by the American Society. of Civil Engineers, 34S East 47th Street. New York., N.Y. 209 SOLtDS* The terms "solids," "suspended," and "dissolved," as used herein, replace the terms "residue," "nonfiltrable," and '"fil- trable" of the previous edition. Solids refer to matter suspended or dissolved in water or wastewater. Solids may affect water or effluent quality adversely in a number of ways. Waters v..-ith high dissolved solids generally are of inferior palatability and may induce an unfavorable physiological reaction in the transient consumer. For these reasons, a limit of SOO mg dissolved solidslL is desirable for drinking waters. Highly mineralized waters also are unsuit- able for many industrial applications. Waters high in suspended solids may be esthetically unsatisfactory for such pur- poses as bathing. Solids analyses are ~- portant in the control of biological and physical wastewater treatment processes and for assessing compliance with regula- tory agency wastewater effluent limitations. 1. Definitions "Total solids" is the term applied to the material residue left in the vessel after evap- -Approved by Standard Methods Committee, 1985. oration of a sample and its subsequent drying in an oven at a defined temperature. Total solids includes "total susPended sol- ids," the portion of total solids retained by a filter, and "total dissolved solids," the portion that passes through the filter. The type of filter holder, the pore size, porosity, ar~and thickness of the filter and the physical nature, particle size, and amount of material deposited on the filter are the principal factors affecting separa-· tion of suspended from dissolved solids. "Fixed solids" is the term applied to the residue of total, suspended, or dissolved. solids after ignition for a specified time at a specified temperature. The weight loss on ignition is called "volatile solids." Deter- minations of fixed and volatile solids do not distinguish precisely between inorganic and organic matter because the loss on ig- nition is not confined to organic matter. It includes losses due to decomposition or volatilization of some mineral saIts. Better characterization of organic matter can be made by such tests as total organic carbon (Section 505), BOD (Section 507), and COD (Section 508). "Settleable solids" is the term applied to the material settling out of suspension ., SOlIDS I T ctal ., within a defined period. It may include ðoating material, depending on the tech- nique (209E.3b). .~~: -. 2. Sources of Error and Variability :: The temperature at which the residue is dried has an important bearing on results, because weight losses due to volatilization of organic matter, mechanically occluded water, water of crystallization, and gases from heat-induced chemical decomposi- tion. IS well as weight gains due to oxi- dation, depend on temperature and time of heating. Residues dried at 103 to 105°C may re- tain DOt only water of crystallization but also some mechanically occluded water. Loss of CO2 will result in conversion of bicarbonate to carbonate. Loss of organic matter by volatilization usuaUy will be very slight Because removal of occluded water is ma.rgina1 at this temperature, attainment of constant weight may be very slow. Residues dried at 180 ± 2°C will lose almost all mechanicaIJy occluded water. Some water of crystallization may remain, tspeciaIJy if sulfates are present. Organic Dlatter may be lost by volatilization, but not completely de.6troyed. Loss of CO2 re- aults from conversion of bicarbonates to cirbonates and carbonates may be decom- ÞOsed partiaHy to oxides or basic salts. ~rne chloride and nitrate salts may be lost. general, evaporating and drying water IaInples at 18crC yields values for dissolved j:. solids closer to those obtained through r ~ I ¿J_., "" ""''::' ~.....,- ~T ry:, ~..í. ]; t ~: Î: summation of individually determined mineral species than the dissolved solids values secured through drying at the lower temperature. Results for residues high in oil or grease may be questionable because of the diffi- culty of drying to constant weight in a rea- sonable time. Analyses performed for some special purposes may demand deviation from the stated procedures to include an unusual constituent with the measured solids. \\Thenever such variations of technique are introduced, record and present them with the results. 3. Sample Handling and Preservation Use resistant-glass or plastic bottles, pro- vided that the material in suspension does not adhere to container walls. Begin anal- ysis as soon as possible because of the im- practicality of preserving the sample. Refrigerate sample at 4°C up to· analysis to minimize microbiological decomposition of solids. 4. Selection of Method Methods A through E are suitable for the determination of solids in potable, sur- face, and saline waters, as wen as domestic and industrial wastewaters in the range up to 20 000 mgIL. Method F is suitable for the determi- nation of solids in sediments, as well as solid and semisolid materials produced during water and wastewater treatment. 209 A. Total Solids Dried at 103-1 05°e ,. General Discussion .. :t\' Q, Principle: A wen-mixed sample is . aÞOrated in a weighed dish and dried to constant weight in an oven at 103 to 105°C. The increase in weight over that of the empty dish represents the total solids. The results may not represent the weight ot 93 I! () ¡ t ~l.·.' !.. I oM ¡ - f ~1 - f 1 W I :';1 Î ¡ : Î ¡ ,/ j. i j J ;n :,' I, f,eIf ! l ·.1 t . 1. 1,. 'r f, I' 1: ! r ·t- ,; : - ~ ~ } t: ~¡ -' SOLIDS / T 0181 Dissolved 209 8. 95 Total Dissolved Solids Dried at 180°C 1. General Discussion a. Principle: A well-mixed sample is fil- tered through a standard glass fiber filter. and the filtrate is evaporated to dryness in a weighed dish and dried to c.ons~nt weight at 180"C. The increase In dIsh weight represents the total dissolved solids. Tbe results may not agree with the the- oretical value for solids calculated from chemical analysis of sample (see above). Approximate methods for correlating chemical analysis with di~solved solids are available. 1 The filtrate from the total sus- pended solids determination (Section 209C) may be used for determination of total dissolved solids. b. Interferences: Highly mineralized waters with a considerable calcium. mag- nesium, chloride, and/or sulfate content may be hygroscopic and require prolonged drying, proper desiccation. and rapid weighing. Samples high in bicarbonate re- quire Careful and possibly prolonged drying at 18ere to insure complete conversion of bicarbonate to carbonate. Because exces- sive residue in the dish may form a water- trapping crust, limit sample to no more than 200 mg residue. 2. Apparatus Apparatus listed in 209A.2a-d is re- quired, and in addition: a. Glass-fiber filter disks· without or- Þnic binder. b. Filtration apparatus: One of the fol- lOwing, suitable for filter disk selected: 1) Membrane filter funnel. -- ·Whatrnan ~ 934AH: Gelman type AlE; Millipore t}'þe AP4O; Of equivaJenL Available in diameters of 2.2 ern to 4.7 an. 2) Gooch crucible, 25-mL to 4O-mL ca- pacity. with Gooch crucible ~pter. . 3) Filtration apparatus WIth reservOlT and coarse (40- to 6O-µm) fritted disk as filter support. c. Suction flask, of sufficient capacity for sample size selected. d. Drying oven. for operation at 180 ± 2°C. 3. Procedure a. Preparation of glass-fiber filter disk' Insert disk with wrinkled side up into fiJ- tration apparatus. Apply vacuum and wash disk with three successive 20-mL volumes of distilled water. Continue suction to re- move all traces of water. Discard washings. b. Preparation of evaporating dish: ~f v~J- atile solids are to be measured. Igmte cleaned evaporating dish at 550 ± serc for 1 h in a muffle furnace. IT only total dissolved solids are to be measured, heat clean dish to 180 ± 2°C for 1 h in an oven. Store in desiccator until needed. Weigh im- mediately before use. c. Selection of filter and sample sizes: Choose sample volume to yield between 2.S and 200 mg dried residue. If more than 10 min are required to complete filtration, in- crease filter size or decrease sample volume but do not produce less than 2.5 mg resi- due. d. Sample analysis: Filter measured vol- ume of well-mixed sample through glass- fiber filter. wash with three successive 10- mL volumes of distilled water. allowing complete drainage between washings. and continue suction for about 3 min after fil- tration is complete. Transfer filtrate to a weighed evaporating dish and ~'aporate to dryness on a steam bath. If filtrate volume exceeds dish capacity add successive por- ·1 . :I ,I ; ¡ ¡ ! , f f t ¡ , i ¡: ~ ~.,. ~.' 1¡' I' i-- I 'í. " i [' f t'. II . ': ì .. f I:: r ¡: i --- 96 tions to the same dish after evaporation. Dry for at least 1 h in an oven at 180 ± 2°C, cool in a desiccator to balance tem- perature, and weigh. Repeat drying cycle of drying, cooling, desiccating, and weigh- ing until a constant weight is obtained or until weight loss is less than 4% of previous weight or 0.5 mg, whichever is less. 4. Calculation mg total dissolved solids/L (A - B) X 1000 sample volume, mL . - --.-----=---~- ----'---'-.-- ---- "-' PHYSICAL EXAMINATION (2OQ) where: A = weight of dried residue ~ dish, mg, and B = weighç of dish, mg. 5. Precision and Accuracy Single-laboratory analyses of 77 samples of a known of 293 mgIL prepared as S0- lution B (Section l04B) were made with a standard deviation of differences of 21.20 mg/L. 209 C. Total Suspended Solids Dried at 103-1 05°C 1. General Discussion a. Principle: A well-mixed sample is fil- tered . through a weighed standard gIass- fiber filter and the residue retained on the filter is dried to a constant weight at 103 to 105°C. The increase in weight of the filter represents the total suspended solids. If the suspended material clogs the filter and pro- longs filtration, the difference between the total solids and the total dissolved solids may provide an estimate of the total sus- pended solids. b. Interferences: Exclude large floating particles or submerged agglomerates of nonhomogeneous materials from the sam- ple if it is determined that their inclusion is not desired in the final result. Because excessive residue on the filter may form a water-entrapping crust, limit the sample size to that yielding no more than 200 mg residue. For samples high in dissolved sol- ids thoroughly wash the filter to ensure removal of the dissolved material. Pro- longed filtration times resulting from filter clogging may produce high results owing to excessive solids capture on the clogged filter. 2: Apparatus Apparatus listed in Sections 209A.2 and 209B.2 is required, except for evaporating dishes, steam bath, and 18ere drying oven. In addition: Planchet,· aluminum' or stainless stee~ 65-mm diam. 3. Procedure a. Preparation of glass-fiber filter disk' Insert disk with wrinkled side up in filtra- tion apparatus. Apply ~-acuum and wash disk With three successive 20-mL portions of distilled water. Continue suction to re- move all traces of water, and discard wash- ings. Remove filter from filtration apparatus and transfer to an aluminum or stainless steel planchet as a support. Al- ternatively remove crucible and filter com- bination if a Gooch crucible is used. Dry in an oven at 103 to 105°C for 1 h. If volatile solids are to be measured, ignite at 550 ± sere for 15 min in a muffle furnace. Cool in desiccator to balance temperature and -Available from New England ~-uclear. Boston, Mass. , or equivalent. sc \\ Ci CI Ie \\ V 5, ~ fi S~ I pi fiJ tc II1 \\ of a! fo F I" st te cc G h dt " d - r t f 1 t p t t ~ s s t SOLIDS/Total. Fixed. & Volatile mLIL. Where a separation of settleable and floating materials occurs, do not esti- mate the floating material as settleable mat- ter. b. Gravimetric: 1) Determine total suspended solids of wel1-mixed sample (Section 209C). 2) Pour a well-mixed sample into a glass vessel of not less than 9 cm diam using not less than 1 L and sufficient to give a depth of 20 em. Alternatively use a glass vessel of greater diameter and a larger volume of sample. Let stand quiescent for 1 hand, without disturbing the settled or floating material, siphon 250 mL from center of container at a point halfway between the surface of the settled material and the liq- uid surface. Determine total suspended sol- ids (milligrams per liter) of this supernatant liquor (Section 209C). These are the non- settleable solids. 4. Calculation mg settleable solids/L = mg total suspended solids/L - mg nonsettleable solids/L 5. Precision and Accuracy Precision and accuracy data are not now available. 209 F. Total, Fixed, and Volatile Solids in Solid and Semisolid Samples ,. General Discussion a. Applicability: This method is appli- cable to the determination of total solids and its fixed and volatile fractions in such solid and semisolid samples as river and lake sediments, sludges separated from Water and wastewater treatment processes, and sludge cakes from vacuum filtration, centrifugation, or other sludge dewatering processes. b. Interferences: The determination of both total and volatile solids in these ma- terials is subject to negative error due to lOSs of ammonium carbonate and volatile or~~c matter during drying. Although ,Jhis 15 true also for wastewater, the effect ~tends to be more pronounced with sedi- ilJ1ents, and especially with sludges and Udge cakes. The mass of organic matter . vered from sludge and sediment re- l11res a longer ignition time than that spec- for wastewaters, effluents, or polluted . aters. Carefully observe specified ignition e and temperature to control losses of volatile inorganic salts. Make all weighings quickly because wet samples tend to lose weight by evaporation. After drying or ig- nition, residues often are very hygroscopic and rapidly absorb moisture from the air. 2. Apparatus All the apparatus listed in Section 209A.2 is required except that a balance capable of weighing to 10 mg may be used. 3. Procedure a. Total solids: 1) Preparation of evaporating dish - If volatile solids are to be measured, ignite a clean evaporating dish at SSO ± SO"C for 1 h in a muffle furnace. If only total solids are to be measured, heat dish at 103 to 105°C for 1 h in an oven. Cool in desiccator, weigh, and store in desiccator until ready for use. 2) Sample analysis a) Fluid samples-If the sample contains enough moisture to flow more or less read- 99 ---. --- 100 ily, stir to homogenize, place 25 to 50 gin a prepared evaporating dish, and weigh. Evaporate to dryness on a water bath, dry at 103 to 105°C for 1 h, cool to balance temperature in an individual desiccator containing fresh desiccant, and weigh. b) Solid samples-If the sample consists of discrete pieces of solid material (dewa- tered sludge, for example), take cores from each piece with a No. 7 cork borer or pul- verize the entire sample coarsely on a clean surface by hand, using rubber gloves. Place 25 to 50 g in a prepared evaporating dish and weigh. Place in an oven at 103 to !OSoC overnight. Cool to balance temperature in an individual desiccator containing fresh desiccant and weigh. b. Fixed and volatile solids: Transfer to a cool muffle furnace, heat furnace to 550 ± serC. and ignite for I h. (If the residue from 2) above contains large amounts of organic matter, first ignite the residue over a gas burner and under an exhaust hood in the presence of adequate air to lessen 209 G. 1. SoKOLOFF, V.P. 1933. Water of crystallization in total solids of water analysis. Ind. Eng. Chern., Anal. Ed. 5:336. PHYSICAL EXAMINATION (~ losses due to reducing conditions and to avoid odors in the laboratory.) Cool in des- iccator to balance temperature and weigh. 4. Calculation % tal lids (A - B) x 100 (:Ita so = C-B ~ 1a. il lids (A - D) X 100 o vo t e so = A _ B M. fixed lids = (D - B) X 100 7D so A-B where: A = weight of dried residue + dish, mg, B = weight of dish. C = weight of wet sample + dish, mg, and D = weight of residue + dish after ignition, mg. 5. Precision and Accuracy Precision and accuracy data are not now available. Reference 209 H. Bibliography THERIAULT, E.J. & H.H. WAGE1'o'HALS. 1923. Studies of representative sewage plants. Pub. Health BulL No. 132. HOWAJlD, e.s. 1933. Determination of total dis- solved solids in water analysis. Inti. Eng. Chem., Anal. Ed. 5:4. SYMONS, G.E. & B. MOREY. 1941. The effect of drying time on the determination of solids in sewage and sewage sludges. Sewage Works 1. 13:936. FISCHE.R. A.J. & G.E. SYMONS. 1944. The deter- mination of settleable sewage solids by weight. ·Water Sewage Works 91:37. DEGE.1\l, J. & F.E. NUSSBERGER. 1956. Notes on § 136.3 btMS1J\ )~~~. FXHI"r-a- V - .ð CFR CIe., 7ÄIII'-' ~,,_~, 40 aR Ch. I (7-1-87 Edition) Envircnmentc TABLE 1 B-LIST OF ApPROVED INORGANIC TEST PROCEÜ'.JRES-Continued TAB! Para~eler. ur'u'ts. a~::J method Refe:·err....e (met"c::: ¡.~. or pag.:j &aJ'Idard I r..etJ-.ods I 16th Ed. 51 "'-ti T ta', fl· rw...-...... 3 I /' I J . n.. n.UTTI-- 0 , ,mg. . ~~"'~, I . I ¡ tollOWed by: , ¡ ~ =~~~~~.~:::::::::::::=:::~:I ~:;:i:::::::::::::i ~:::::::::::::!::::::::::::=~::::=j=:::::::::::::::::::::::::::¡ 52. potassium-total.', mg/L: Digestion I I I, 1.' I followed by: ii, ~i~~~,]~t~~.·~iif:i~·~~r~E~::d~I2i:iiiii :3:' :";!:E:::::~~~:::: I ::~.': :::.: .::::..:=:::.J ~::·I Gravimetric. 103-1.0S'C post was.~ I / I. I ~~~~ ; :::~~.h~~:'~~i::I! :::::.-::::::::::'.'// ::::::::::::::/,:.::==:j ~;'=:::I 58. Rhodium- Tota. I', mgfL Digesticfi, ¡.. I followed by:. 11 í S9. ~I~. ~~;::..~:.-.~~:;¿:::~=:;.I ~~~::::::::::::::.I ;~~:::::=:::::II:::::::::::::.::.:::.,. =::::::::::::::::::::::::::11 bon ' follOWed by: ,¡ ¡ ~ ::;::;;':''''''"°'·.,,::::::::::::::1 ;:;~::::::j ~A::::I :::::::::::::.:.:::::::::::::::1 SC. Selenium- TOlar', 1'T'.g/L Digestior.' . I I ' I followed by: ¡ I J . / ~~::£~=-i~;'~·~;·¡~~~:.·:..::··.i::~:::¡¿;;;~=.a.::¡';·I~~i=¡::/200.7' 61 S,llca-DI5SO!ved. mgiL: 0.45 microc : Iii i fi~~a!lon fol!owed by: ; I I ¡ : ~~~:~~E~:~J:~;..:·...¡:':':':·:~::·.····.··::.I:':;~..··:.J::~~¡~>'.~~~~~..::..··.:.12oo.7. . 62. Sllver- Tolal H. mg!L: Digestion' I ¡ I follo....ed by: . I ! . ¡ ê~~i~~~~;;:i,;,£.~L;:~;I~~;~'":i.~.............~¡.;-:':0-':;/ ;;;;.'. p. 37.' 63. Sodlum- T olal ". mglL Digesbon: , Ii ¡ j fol!owed by: . I: 1 ~"~;~~:::~:: ~;~~;;;:::::::::::::.~7'.::::::::1..30'.:':::1::::::::::::::::::¡>:~'.::":'::::::! ~&,'~:' Flame photomel'lC .................................:.........................! 3259............: D1428-82(Ã).. ....1....._.,....................1 64. Specific conductance, micromhos/' 120.1..............1/ 20S ...............1 D112S-82(A).....! 1-1780-84 ..........1 33.0022 cm at 2S·C: Whea!s~one bridge· I ¡ ¡ 65. Sulfate (as SO.), mglL !!. I Automated COIOrime~'lc. (bariurr 375.1.......... ...j........................!.......................... .._....................1 chlora~ilate). ; i Gravimetriê or ':>7~ :; d:?I' L C" E 8: 1';.-8:'!; T 'J't",j,rr,,,,r,,c 3·5 ~ :::'~ 1 f,-.g~'I:: EPA 1979 Parameter, unit' ASTM USGS· Other . r 70_ ThaIIium- Total : foJlowed by: AI, direct aspirati AA furnace, or .... inductively coup/( 71. Tin-Tota!', mg bwed by: A/-. direct aspirati> AA turnace, ......... 72. Trtanium-Tota!", folbwed by: AA direct aspirati, AA furnace .......... 73. Turbidity, "''TU:Ne 74. Va'\éldium, Tota! 3 tol1owed by; AA direct aspirati< AI;, furnace......,.... Inductive!y couPle Colorimetric (Galli 75 Zinc-Total", mgl Icwe(j by: Aft. direct aspiratk AA furnace ..........~ !nductively coup!~ Colorimetric (Dith, (zlncon¡......·..··....·1 I "Mefh:x:ls for A~ G~~'bt~~~~~~~~o~ 'F:y. ¡he determm~ sc!ut: .'¡,ze. suspen. d.. ed~ "Me!hojs for Cher-me les.s VtgOi'OUS d'g%ti ca:.rt~::mej that tPiS e"',,!oyed. t: is nece~ sh.~_;a!i;,)ns.. t;-'¡e vigor01 co--::a,n·ng large am te:r,r,iq;J€, inductively ~;:;~¿··tn~~~~~:~;~·_a~ NOTE: If the digestJ be cned. _ . I DfSSO!ved mi?!a!s ~ fiit:'at::>r, of the ~m~ be Ofr'<t!ed for AA (dir the fO!~'Jw¡ng criteria: a. h3S a low COD (.¡ b. is vis'bfy tra!')spar~ c. is colorless with Ii d is of öne liquid pr; · The full tex1 01 M Analysis 01 Wa~er and, · Manual d¡stiHa!ìon~ this prSi¡~'J1I1a. 'Y distill '3 A"'nmon!a AUiO:'l1 ~-.-~"'~"r:~i ,I -rC'crl . . .....,.: aç....·~\o,.:.J :n <'-r-:.., 'LIC,~':,TJ' .. -:.. ';" I ~ ...... _ _ ~ .!ï.:" :'ór, ~.ë::':":" ~~rlr; '. ,:',"r, r; \' . ~ I ~ e .. -:o.?l¿''':IE-:! An;.'.'" c. I·.~ ¡;~:~e:~:~ ~¡.~.~;:~ 1 C~rt)':'nj:~.:us :...~ 10'.:' BC'D H.'2 aCl~ ':::'.~"Tt.:!~. A d,::t"..)r;.:. p~=,: .;-]"u"oe fe,' rO?~>(I~ r;1 rE'~')-: (]2:" us,n ~ (t,,, , €-t. Sc:.f~(. 'a~ SI rr,; '3) I ¿ ~ , <:2f. ~ :'; :-I~· ï'lt::r.( (rO-j -.c;1 ('r C;lü'Iml?lr,; I""'='~ .,,-,-= tt.u;;1 6~ S~I' 'e las SO,I rr,~ L TI1',rr¡€-tr.: I r,"j.'1f- ·,:,oare' é6 Su'1aCldn[~ rr.:; L G:I:-,,"e-:.-,: (rT1e~..,,·lenf tl1u'ó': 63 T e<Tl:>er alu'': C The""':'~,etne :?"ë 1 :, -62 3~7 1 . <:~':';) I-~ 7...! :,-P",...: 2.251.. 3" ~2:-C : <::?St, [ ! ::''''-E.~. ~ 42; , :.12E' . D~ 32)-.e2i'; 1701 212 r~Of.:- :". 256 - - ---- § 146.4 . -Yfj ~ ;--:: ' .;':':--i,." ,;{.~" .H':;';::,;!.., ~ '-~';~fix"-: ;~i~:~~ ':,:4: :~,..~, -;~·Ii--::f;;~ è·:~~~%:i -: ~~ç~;- SD H'A means the Safe Drinking Vlater Act (Pub. L. 95-523, as amended by Pub. L. 95-190, 42 U.S.C. 300(£) et seQ. ). Site means the land or 'water area where any facility or activity is phys- ically located or conducted, including adjacent land used in connection with the facility or activity. Sole ûï principal source acquifer means an aquifer which has been des- ignated by the Administrator pursuant to section 1424 (a) or (e) of the SDW A. State Director means the chief ad- ministrative officer of any State or interstate agency operating an ap- proved program, or the delegated rep- resentative of the State Director. If re- sponsibility is divided among two or more State or interstate agencies, "State Director" means the chief ad- ministrati\·e officer of the State or interstate agency authorized to per- form the particular procedure or func- tion to which reference is made. Stratum (plural strata) means a single sedimentary bed or layer, re- gardless of thickness, that consists of generally the same kind of rock mate- rial. Subsidence means the 100T;ering of the natural land surface in response to: Earth movements; lowering of fluid preSS'.lre; remo\'al of underlying sup- porting material by mining or solution of solids, either artificially or from natural causes; compaction due to wet- ting (Hydro compaction); oxidation of organic matter in soils; or added load on the land surface. Surface casing means the first string of well casing to be installed in the well. Total dissolved solids ("TDS") means the total dissolved (filterable) solids as determined by use of the method specified in 40 CFR Part 136. L'IC means the Underground Injec- t ion Control program· under Part C of the Safe Drinking \Vater Act, includ- ing an "appro\'ed program," Underground injection means a .. we 11 inj ection." Underground source of drinking u:ater (USD\V) means an aquifer or its portion: ( 1 )(0 Which supplies any public \\-ater system; or 40 CFR th. I (7-1-87 Edition) (ii) Which contains a suffic¡tn~ quantity of ground water to SUPply" public water system; and <A) Currently supplies drb.k¡n~' water for hum3...'1 consumption; or r (B) Contains fewer than 10,000 mg¡1 total dissolved solids; and (2) Which is not an exempted aqui fer. USDW means "underground source of drinking water. ,. Well means a bored, drilled or dri\'l':-r. shaft, or a dug hole, whose depth b greater than the largest surface di· mension. Well injection means the subsurface emplacement of fluids through a bored, drilled or driven well; or through a dug well, where the depth of the dug well is greater than tht largest surface dimension. Well plug means a watertight anò gastight sEal installed in a borehole or well to prevent movement of fluids. Well stimulation means several proc- esses used to clean the well bOTE. en, large channels, and increase pore space in the interial to be injected thus making it possible for wastewater to mm:e more readily into the form2 tion, and includes 0) surging, (2) jet, ting, (3) blasting, (4) acidizing, (5) hy· draulic fracturing, Well monitoring means the measure- ment. by on-site instruments or labo, ratory methods, of the quality 0: water in a well. <Clean Water Act. Ssfe Drinking Wa:€': .-\c Clea...ì Air Act, Resource ConsenaUc;;-: c.::~ Recovery Act: 42 -C,S.C. 6905, 6912, 69::~ '6927.6974) (45 FR 42500, June 24, 1980. as amended a: 46 FH 43161. Aug. 27. 1981; 47 FR 4998. Ftt 3. 1982; 48 FR 14293, Apr. I, 1983J § 146..t Criteria for exempted aquifers. An aquifer or a portion thereo~ which meets the criteria for an '·ur-:- derground source of drinking v;ater·· in § 146.3 may be determined unàer <if CFR 144.8 to be an "exempteà aqu:' fer" if it meets the following criteri:J., (a) It does not currently serve as ~ source of drinking v:atc¡'; and (b) It cannot now and will not Lrl tf::t future serve as a source of drinkir,,:: water because: 662 (1) It is mi thermal ene demonstrate part of a pe II or III ope or hydrocar Quantity an. be commerCl (2) It is si tIOD which for drinking cally or tee (3) It is would be œllY iIDpr fit for h (4) It is 1 mining ar catastrophi (c) The to of the gro a..'1d less th reasona bb' water syste (Clean Water Clean Air Ac Recovery Ac 6927,6974) [45 PH 42500 4'i FR 4998, L 1983 J § J.t6.5 Cbs. Injection lows: (a) Class tors of haz ~ee~~ t~~~c~~ ,",,·aste bene tion co. D. t.a....... ('/4) mile 0 ground SQ _ (2) Othe disposal w~ neath the I taining, wit well bore. ~. drinking w (b) Cla-s ~luids: (1) \Vhic in connect natural g commingle gas plants of product waters ar waste at t 93-133 92 ROSEN, A.A. 1970. Report of research committee on tastes and odors. J. Amer. Water Works Ass. 62:59. SU'FFET, I.H. & S. SEG..tù.L. 1971. Detecting taste and odor in drinking water. J. Amer. Water Works Ass. 63:605. GELDARD, F.A. 1972. The Human Senses. John Wiley & Sons, New York, N.Y. PHYSICAL EXA.!a..1!NATION (200) STAHL. W.H., ed. 1973. Compilation of Odor and Taste Threshold Values Data. Amer. Soc. Testing & Materials Data Ser. DS 48, Phil- adelphia, Pa. AMERIc........ SocIETY FOR TESTING Al'o"D MATE- RIAlS. 1973. Annual Book. of ASTM Stand. ards. Part 23, D-1292-65, ASTM, Philadelphia. Pa. 208 OXYGEN TRANSFER* · A standard for the measurement of oxygen transfer in clean water has been adopted by the American Society of Civil Engineers, 34S East 47th Street, New York, N.Y. 209 SOLlDS* The terms "solids," "suspended," and "dissolved," as used herein, replace the terms "residue," "nonfiltrable," and "fil- trable" of the previous edition. Solids refer to matter suspended or dissolved in water or wastewater. Solids may affect water or effluent quality adversely in a number of ways. Waters with high dissolved solids generally are of inferior palatability and may induce an unfavorable physiological reaction in the transient consumer. For these reasons, ~ limit of 500 mg dissolved solidslL is desirable for drinking waters. Highly mineralized waters also are unsuit- able for many industrial applications. Waters high in suspended solids may be esthetically unsatisfactory for such pur- poses as bathing. Solids analyses a..--e im- portant in the control of biological and physical wastewater treatment processes and for assessing compliance with regula- tory agency wastewater effluent limitations. 1. Definitions "Total solids" is the term applied to the material residue left in the vessel after evap- -Approved by Standard Methods Committee, 1985. oration of a sample and its subsequent drying in an oven at a deñned temperature. Total solids includes "total suspended sol- ids," the portion of total solids retained by a filter, and "total dissolved solids," the portion that passes through the filter. The type of filter holder, the pore size, porosity, area, and thickness of the filter and the physical nature, particle size, and amount of material deposited on the filter are the principal factors affecting separa- tion of suspended from dissolved solids. "Fixed solids" is the term applied to the residue of total, suspended, or dissolved solids after ignition for a specified time at a specified temperature. The weight loss on ignition is called "volatile solids." Deter- minations of fixed and volatile solids do not distinguish precisely betv.¡een inorganic and organic matter because the loss on ig- nition is not confined to organic matter. It includes losses due to decomposition or volatilization of some mineral salts. Better characterization of organic matter can be made by such tests as total organic carbon (Section 505), BOD (Section 507), and COD (Section 508). "Settleable solids" is the term applied to the material settling out of suspension SCUDS/Total within a defined period. It may include Boating material, depending on the tech- nique (209E.3b). 2. Sources of Error and Variability The temperature at which the residue is dried has an important bearing on results, because weight losses due to volatilization of organic matter, mechanically occluded water, water of crystallization, and gases from heat-induced chemical decomposi- tion, as well as weight gã.ins due to oxi- dation, depend on temperature and time of .<-, heating. .~ Residues dried at 103 to 105°e may re- ~. tain not only water of crystallization but Wt also SOme mechanica1ly occluded water. ','(, Loss of CO2 wilJ result in conversion of i:,5 bicarbonate to carbonate. Loss of organic " matter by volatilization usuaBy will be very slight. Because removal of occluded water is Dlargina] at this temperature, attainment of constant weight may be very slow. Residues· dried at 180 ± 2°e will lose I1.mOSt all mechanically occluded water. Some water of crystallization may remain, e8pecia1Jy if sulfates are present. Organic IIlatter may be lost by volatilization, but not completely destroyed. Loss of e02 re- auJts from conversion of bicarbonates to carbonates and carbonates may be decom- PGsed partial]y to oxides or basic salts. ~rne chloride and nitrate salts may be lost. general, evaporating and drying water Ba.tnples at I 8ere yields values for dissolved IOlids closer to those obtained through 1,c ~ ¡;:><-~6 --:;..=-..; ...~ -~~. -''--~ -c.. ,:-._::. :- summation of individually determined mineral species than the dissolved solids values secured through drying at the lower temperature. Results for residues high in oil or grease may be questionable because of the diffi- culty of drying to constant weight in a rea- sonable time. Analyses performed for some special purposes may demand deviation from the stated procedures to include an unusual constituent with the measured solids. Whenever such variations of technique are introduced, record and present them with the results. 3. Sample Handling and Preservation Use resistant-glass or plastic bottles, pro- vided that the material in suspension does not adhere to container walls. Begin anal- ysis as soon as possible because of the im- practicality of preserving the sample. Refrigerate sample at 4°e up to analysis to minimize microbiological decomposition of solids. 4. Selection of Method Methods A through E are suitable for the determination of solids in potable, sur- face, and saline waters, as well as domestic and industrial wastewaters in the range up to 20 000 mg/L. Method F is suitable for the determi- nation of solids in sediments, as weB as solid and semisolid materials produced during water and wastewater treatment. 1, General Discussion 209 A. Total Solids Dried at 1'03-1050C t\1 C2. Principle: A welJ-mixed sample is aPorated in a weighed dish and dried to ;: ) ,~ constant weight in an oven at 103 to 105°C. Tbe increase in weight over that of the empty dish represents the total solids. The results may not represent the weight of 93 r c ~ SOLIDS I Total Dissolved 95 . ;f it -~ ~ i r ì -I ct :1 .L I' ·i~···'·';. ' ., ., , IJ; f ¡ 209 8. Total Dissolved Solids Dried at 180°C I J I J 1. General Discussion a. Principle: A well-mixed sample is fil- tered through a standard glass fiber filter, and the filtrate is evaporated to dryness in a weighed dish and dried to constant weight at 180°e. The increase in dish weight represents the total dissolved solids. The results may not agree with the the- oretical value for solids calculated from chemical analysis of sample (see above). Approximate methods for correlating chemical analysis with dissolved solids are available. I The filtrate from the total sus- pended solids determination (Section 209C) may be used for determination of total dissolved solids. b. Interferences: Highly mineralized waters with a considerable calcium, mag- nesium, chloride, and/or sulfate content may be hygroscopic and require prolonged dr)ing, proper desiccation, and rapid weighing. Samples high in bicarbonate re- quire careful and possibly prolonged drying at IScrC to insure complete conversion of bicarbonate to carbonate. Because exces- sive residue in the dish may form a water- trapping crust, limit sample to no more than 200 mg residue. 2. Apparatus Apparatus listed in 209A.2a-d is re- quired, and in addition: a. Glass-fiber filter disks- without or- Þnic binder. b. Filtration apparatus: One of the fol- lowing, suitable for filter disk selected: 1) Membrane filter funnel. -- ."''batman grade 934AH; Gelman type AlE; Millipore t}'þe AP40; or equivalent. Available in diameters of 2.2 tlIJ to 4.7 em. 2) Gooch crucible, 25-mL to 4O-mL ca- pacity, with Gooch crucible adapter. . 3) Filtration apparatus with reservOir and coarse (40- to 6O-µm) fritted disk as filter support. c. Suction flask. of sufficient capacity for sample size selected. d. Drying oven, for operation at 180 ± 2°e. 3. Procedure a. Preparation of glass-fiber filter disk' Insert disk with wrinkled side up into fil- tration apparatus. Apply vacuum and wash disk with three successive 20-mL volumes of distilled water. Continue suction to re- move all traces of water. Discard washings. b. Preparation of evaporating dish: ~f v~l- atile solids are to be measured, Igmte cleaned evaporating dish at 550 ± 5O"C for 1 h in a muffie furnace. If only total dissolved solids are to be measured, heat clean dish to 180 :t 2°e for r h in an oven. Store in desiccator until needed. Weigh im- medfately before use. c. Selection of filter and sample sizes: Choose sample volume to yield between 2.5 and 200 mg dried residue. If more than 10 min are required to complete filtration, in- crease filter size or decrease sample volume but do not produce less than 2.5 mg resi- due. d. Sample analysis: Filter measured vol- ume of well-mixed sample through glass- fiber filter, wash with three successive 10- mL volumes of distilled water, allowing complete drainage between washings, and continue suction for about 3 min after fil- tration is complete. Transfer filtrate to a weighed evaporating dish and evaporate to dryness on a steam bath. If filtrate volume exceeds dish capacity add successive por- -r-____,..____~_......~ 96 tions to the same dish af+..er e\-'aporation. Dry for at least I h in an oven at 180 ± 2°C, cool in a desiccator ~ balance tem- perature, and weigh. Repeat dI)ing cycle of dI)IDg, cooling, desiccating, and weigh- ing until a constant weight is obtained or until weight loss is less than 4% of previous weight or O.S mg, whichever is less. 4. Calculation mg total dissolved solids/L (A - B) X 100') sample volume. mL --. PHYSICAL EXAMINATION (200) where: A = weight of dried residue + dish, mg, and B = weight of dish, mg. 5. Precision and Accuracy Single-laboratory analyses of 77 samples of a known of 293 mgIL prepared as So- lution B (Section l04B) were made with a ~da.rd deviation of differences of 21.20 mgIL. 209 C. Total Suspended Solids Dried at 103-1 05°C 1. General Discussion a. Principle: A well-mixed sample is fil- tered through a weighed st..andard glass- fiber filter and the residue retained on the filter is dried to a constant weight at 103 to IOS"C. The increase in weight of the filter represents the total suspended solids. If the suspended material clogs the tilter a..Tld pro- longs filtration, the difference between the total solids and the total dissolved solids may provide an estimate of the total sus- pended solids. b. Interferences: Exclude large floating particles or submerged agglomerates of nonhomogeneous materials from the sam- ple if it is determined that their inclusion is not desired in the final result. Because excessive residue on the filter may form a water-entrapping crust, limit the sample size to that yielding no more than 200 mg residue. For samples high in dissolved sol- ids thoroughly wash the filter to ensure removal of the dissolved materiaL Pro- longed filtration times resulting from filter clogging may produce high resuhs o-wIDg to excessive solids capture on the clogged filter. .... 2~ Apparatus Apparatus listed in Sections 209A.2 and 209B.2 is required, except for evaporating dishes, steam bath, and 18O"C drying oven. In addition: Planchet, * aluminum or stainless steeL 65-mm diam. 3. Procedure a. Preparation of glass-fiber filter disk: Insert disk with wrinkled side up in filtra- tion apparatus. Apply vacuum and wash disk with three successive 20-mL portions of distilled water. Continue suction to re- move all traces of water, and discard wash- ings. Remove filter from filtration apparatus and transfer to an aluminum or stainless steel planchet as a support. Al- ternatively remove crucible and filter com- bination if a Gooch crucible is used. Dry in an oven at 103 to 105°e for 1 h. If volatile solids are to be measured, ignite at 550 :t 5<rC for 15 min in a muffle furnace. Cool in desiccator to balance temperature and -Available from New England Nuckar. Boston. Mass., or equivalent. s' "- c' c· Ie ~ V ; I t ¡ i .1 I f ~ i ! . J J I i 51 SZ fi] 58 t t i I i f f i Î I i f p~ fi1 to tIl \V of ag fo o p~ st te C( G h dt \\ d J f J: ~ - I s t s J t :!- ~ ì I COAS~ - ~ONE BOUNDARIES OF ALAISKA .',- - .' . .,.. ~ I ~.. 1'..1 ..... ~ '0';--~r " ,- -I'''¡~I¡~~:~ . ___.___~~ n_" JUNE 1988 5 0 5 10 16 ~_~_:::._.-=--_- __===-:-------::;::;:r ___--t::::::: 'kr..::f.:.~:::__;: -.~~.-------~=----4º_-__:::~1> KilOMETERS 20 _:=--:._ ..2ì' u q E S Based on a USGS map Unlver8al Transverse Mercator Projection ( ~ 7R.STFCS Ft/t Att.óH,,,rA .. ClM -MA' - 1-1"-' , r . 1 I ! ! I I TYONEK #89 Im'llll I ! ~..... ,._:::-- --:~-~ \' I I E~=I ::~; ~~' I I . III l] LOCATION INDEX '-...... _.,Þ Inland Boundary Seaward Boundary --- District Boundary ------- BOUNDARY DESCRIPTION Federal Lands: Excluded from Alaska's coastal zone boundaries are "those lands owned, leased, held in trust or whose use is otherwise by law subject solely to the discretion of the Federal Government, its officers or agents. .. (15 Cn< 923.33). Activities on these lands are subject to the consistency provisions of section 307 of the Coastal Zone Management Act of 1972, as amended. Seaward Boundarv: The seaward coastal zone boundary is the "outer limit of the United States territorial sea" (15 CFR 923.32) , which is the "three geographical mile line" (43 CFR 330::'.1). All offshore waters on this map are within t.t¡e coastal zone. ~gninsula Borouah: The inland ccastal zone boundary in the Kenai peninsula Borough is the interim coastal zc:>ne boundary. The inland boundary west of Cook Inlet in this portion of the Kenai Peninsula Borough includes the lands and waters within: (1) the 1000-foot elevation contour south of the Chuitna River, (2) the 400-foot elevation contour north of the chui tna River, and (3) other areas as delineated on this map. The inland boundary on the Kenai Peninsula in this portion of the Kenai peninsula Borough includes all lands and waters" ~nuska-Susitna Borouah: The inland coastal zone bound:lry in this portion of the Matam,:.5ka-Susitna Boro¡,;gh includes all islands and the lands and waters within: (1) the 400-foot eleva1:.lon contour near Beluga Lake; (2) the 200-foot elevatior: contour east of the Parks Highway; (3) the S~:"e.ntna and Kash-..itna rivers and Talachulitna, Sheep, Little Willow, and Willow creeks upstream to the lOOO-foot elevation contour, including all lands and waters within the 100-year floodplain or 200 feet on each side as measured from the ordinary high vater mark I whichever is greater (includes all lands encompassed by the extended boundary, such as islands in a braided stream or river, even though th':!y may be higher. in elevation than the 100-year floodplain); and (4) other areas wi thin the boroug!"_ boundary I township lines, or west of the Parks Eighway, as delineated on this map. Reference to 1: 53,360 USGS topographic maps, Federal Emergency Mr;nagerncnt Agency Flood Ins'lrance Rate maps, or otì",r information which defines the 100-yea::- floodplain may be necessary to determine if the ab,,",'c criteria apply and whether the use or activi1:y will lie wi thil1 the coastal zone. li\!.!Ü£i.P~.Y-º.f._ Anc'iorage: The inland c,oastal zone boundary in this portion of the Mun.lcipality of Anchorage includes Fire Island and the lands i!lnd waters within: (1) a zone extending 1,320 fec:t inland, measured horizontally, from the extent of the ::'OO-year coastal flood; (2) the 100-year floodplain or 200 feet from the center (.hichever is greater) of each river and stream intersected by the 1, nO-foot zone up to the 1000-foot elevation contour; and (3) other areas as delineated on this map. Reference to 1:25,000 USGS topog::.:!.?hic maps, Federal Emergency Kanagement Agency Flood Insurance Rate maps, or the Anchorage Coastal Management Program may be necessary to determine if the above criteria apply and whether the use or activity will lie within the coastal zone. #6 .~~~~ .- ..- ""'-~- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 2 In the Matter Re: 3 Lewis River Field 4 5 HEARING BEFORE THE COMMISSION 6 ON 7 UNOCAL'S APPLICATION FOR AN AQUIFER EXEMPTION LEWIS RIVER WELL D-1 8 FOR THE BOARD: 9 Chat Chatterton, Chairman 10 Lonnie C. Smith, Member 11 Steven R. Porter, Attorney General's Office 12 FOR THE APPLICANT: 13 Roy Roberts, Unocal 14 FOR TRUSTEES FOR ALASKA: RECEIVE.D 15 Randall Weiner Robert Dizotell JA\\~ 1" a 1.....;C;¡ ¡ \I ¡ .1:.1\\ ,:j 16 Alaska .oJl. &.... GasCons. ~~... 0,,,. ~ß I,~\< . rAn"'.hnftlftd. .. ,. ·''4,OIßtIJJfL'"'' . FOR ALASKA CENTER FOR THE ENVIRONMENT: 17 Sue Libenson 18 * * * * * 19 20 3001 Porcupine Drive Anchorage, Alaska January 13, 1989 9:00 o'clock a.m. 21 22 23 24 25 R & R COURT REPORTERS 810 N STREET, SUITE 101 277-0572 - 277-0573 509W.3RDAVENUE 277-8543 1007 W. 3RD AVENUE 272-7515 ANCHORAGE, ALASKA 99501 - ""~ ~ '-' 2 PRO C E E DIN G S 2 MR. CHATTERTON: WeIll we'll bring this 3 hearing to order, if we may. The time is 9:05 on the 13th of 4 January, 1989, and the place is 3001 Porcupine Drive, the 5 conference room of the Oil and Gas Conservation Commission. 6 I'm Chat Chatterton and will be presiding over the 7 hearing. To my extreme left, your right, is Meredith Downing of 8 the R & R Court Reporters. She will be taking these proceedings 9 down, and immediately to my left is Commissioner Lonnie Smith. 10 To my right is Steve Porter with the Department of Law, the 11 Attorney GeneralIs Office, who is our -- provides -- is our 12 attorney I guess is the best way to put it. 13 And without any further adieu, why, Lonnie, would you 14 read into the record the purpose of this get together? 15 MR. SMITH: The purpose of this public hearing 16 was stated in the public notice published December the 14th, 17 1988, in the Daily News, Anchorage Daily News. 18 "The State of Alaska, Oil and Gas Conservation 19 Commission, reference, the application of Unocal for a fresh 20 water aquifer exemption, Lewis River, Well D-l. 21 "Unocal by letter dated December the 1st of 1988 has 22 requested a fresh water aquifer exemption for formations 23 occurring below 2300 feet measured depth in the Lewis River Well 24 D-l in line with a one and a quarter mile radius of the well. 25 "A person who may be harmed if the requested order is R & R COURT REPORTERS 810 N STREET, SUITE 101 277-0572 - 277-0573 1007 W. 3RD AVENUE 272-7515 509 W. 3RD AVENUE 277-8543 ANCHORAGE, ALASKA 99501 3 4 5 6 7 8 9 10 11 12 13 ....~- 14 >.- .""'~ -- 3 issued may file a written protest prior to December the 29th, 2 1988, with the Alaska Oil and Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, Alaska, and request a hearing on the matter. If the protest is timely filed and raises a substantial and material issue crucial to the Commission's decision, a hearing on the matter will be held at the above address at 9:00 a.m. on January the 13th, 1989, in conformance with 28 AAC 25.540. If a -- if a hearing is to be held, interested parties may confirm this by calling the Commission's office at 279-1433 after December 29th, 1988. If no proper protest is filed, the Commission will consider the issuance of an order without a hearing. "Signed, Lonnie C. Smith, Commissioner, Alaska Oil and Gas Conservation Commission. II MR. CHATTERTON: There was a request for a 15 hearing, and so that is the purpose, and that was filed timely 16 with -- with the Commission within the 15-day period, and so that 17 is the reason we are holding the hearing. 18 The the procedure for the hearing will be strictly in 19 compliance with our regulation, which is 20 AAC 25.540, and for 20 your quick reference, just quickly to summarize that procedure, 21 why the -- we will swear in anyone that's wishing to testify here 22 immediately after I complete my briefing here, and then we will 23 provide -- permit the applicant to present any testimony they 24 wish to put into the public record, and we may have of the -- of 25 R & R COURT REPORTERS 810 N STREET, SUITE 101 277-0572 - 277-0573 509 W. 3RD AVENUE 277-8543 1007W.3RDAVENUE 272-7515 ANCHORAGE, ALASKA 99501 ..-- 4 that -- of the applicant, but we'll hold our questions until you 2 have completed the -- completed your direct. Anyone else wishing 3 to testify will then follow your -- your presentation. 4 And, of course, we -- we don't -- the -- the regulation 5 does not permit cross examination. All questioning of the 6 witness -- of the witnesses will be directed through the chair 7 from the public, but anyone may present us a question present 8 me or Lonnie with a question, preferably in a written form, and 9 if we believe it's germane to the determination that we're faced 10 with making, why we certainly will pass that question on and -- 11 and provide -- get an answer for you. That's about the quickest 12 way we can proceed. 13 So without further adieu we'll proceed, and our -- why 14 don't we swear in all those that wish to testify at this point in 15 time, if you would be willing to so indicate? One, two, three 16 okay. Union, do you have some people that are going to testify? 17 MR. ROBERTS: We -- yes. Ilm sorry. 18 MR. CHATTERTON: Well, if you 19 MR. ROBERTS: If -- if necessary. 20 MR. CHATTERTON: Those that are going to present 21 testimony, would you please step forward right here and Lonnie 22 will do his little thing? 23 (Mr. Smith swears in all witness together) 24 MR. SMITH: Thank you. 25 MR. CHATTERTON: Thank you, Lonnie, very good. .'-.._~ R & R COURT REPORTERS 810NSTREET,SUITE 101 277-0572 - 277-0573 509 W. 3RD AVENUE 277-8543 1007 W. 3RD AVENUE 272-7515 ANCHORAGE, ALASKA 99501 ~~ '~ 14 15 16 17 18 19 20 21 22 23 24 25 ·"C=' --- '_/ 5 For -- for those that may have arrived a little bit after 2 we opened the -- the hearing, why I will reintroduce the head 3 table, and I'm Chat Chatterton and will be presiding as the chair 4 of this hearing -- for this hearing. At my extreme left, your 5 right is Meredith Downing, of the R & R Court Reporters. She 6 will be taking the -- making a record of -- of these proceedings. 7 Immediately to my left is Lonnie -- Commissioner Lonnie Smith, 8 and to my right is Steve Porter of the Attorney General's Office, 9 and I'm Chat Chatterton. 10 I would ask your indulgence. Everyone seems to have 11 gotten as far as possible away from me, and -- and I know I don't 12 blame them I guess, but I would ask your indulgence. I do have 13 an impairment of hearing and would appreciate you speaking up from your far distance there, so if -- if I can't quite read you, why I'll -- I'll scream, okay? All right. Applicant, would you proceed, please? MR. ROBERTS: Thank you. My name is Roy Roberts. I'm Unocal's environmental engineer for the Alaska District. Unocal would like to submit comments in written form concerning the proposed aquifer exemption application in response to the questions and comments that have been submitted by the Alaska Center for the Environment. Unocal employees will be ...... MR. CHATTERTON: Hold one, please. MR. ROBERTS: Would you like these read into the R & R COURT REPORTERS 810 N STREET, SUITE 101 277-0572 - 277-0573 509W.3RDAVENUE 277-8543 1007 W. 3RDAVENUE 272-7515 ANCHORAGE, ALASKA 99501 , ''''"'-"'- '"--' 6 ~~- record, or would you ..... 2 MR. SMITH: I think at the very least ..... 3 MR. CHATTERTON: Let's go off the record for a 4 minute. 5 (Off record) 6 (On record) 7 MR. CHATTERTON: The -- while we were off the 8 record, the chair chose to try and gain some information about 9 rather an unusual procedure in -- in the chair's experience 10 anyway, and try to clarify it as to the procedure that we're 11 following under 540. Normally what the chair is looking for is 12 to have data presented to us that will support the application. 13 That is from the applicant we expect to get data that will 14 support his application, and not any cross -- cross discussion of 15 what others may have said. So we're looking basically for those 16 things that will aid us in making our determination. We have 17 pointed out to the people that that's what we're after, and so 18 now we may proceed. Mr. Roberts? 19 MR. ROBERTS: Thank you. Yes, it's Roy Roberts 20 again. Unocal would like for the record to ask that our 21 exemption permit be considered part of the public record for this 22 hearing and that Unocal feels that the information submitted 23 within that permit application shows justification for the 24 aquifer exemption. 25 At this time we do not have any additional information -c~ R & R COURT REPORTERS 810NSTREET,SUITE 101 277-0572 - 277-0573 509 W. 3RD AVENUE 277-8543 1007W.3RDAVENUE 272-7515 ANCHORAGE, ALASKA 99501 .,.-- c_ '--- 7 that has shown to be necessary to comply with the regulations as 2 they are written. Thank you. 3 MR. CHATTERTON: You have nothing to submit to 4 the -- in our deliberations I take it? 5 MR. ROBERTS: No. 6 MR. CHATTERTON: Very fine. 7 MR. SMITH: Let me say here that I will then 8 input into the record as Exhibit One, with your concurrence, as 9 the aquifer exemption exemption application previously 10 submitted to the Commission. 11 MR. CHATTERTON: Are there others that chose to 12 testify in this matter before us? Yes, sir. 13 MR. WEINER: Would it be appropriate for me to 14 come to the table? 15 MR. CHATTERTON: I would be tickled to death. I 16 don't have to strain my ear then. 17 MR. WEINER: Sure. 18 MR. SMITH: Yes, and be sure you're in front of a 19 microphone for any testimony that should be on the record. Any 20 statements or 21 MR. CHATTERTON: Yeah, the ..... 22 MR. SMITH: .. ... testimony that should be in 23 the record. 24 Mr. Weiner, proceed. MR. CHATTERTON: 25 MR. WEINER: Thank you, Commissioners. My name R & R COURT REPORTERS 810 N STREET, SUITE 101 277-0572 - 277-0573 509W,3RDAVENUE 277-8543 1007 W, 3RD AVENUE 272-7515 ANCHORAGE, ALASKA 99501 T<____~/ 17 18 19 20 21 22 23 24 25 -~-~_.5"'" '--- 8 is Randell Weiner. I'm the executive director of Trustees for 2 Alaska and represent that organization before these hearings. Trustees for Alaska has numerous concerns with the 3 application presented here today by Unocal, and 11m going to 4 detail those concerns at this time. 5 Unocal has not applied for permits from the Alaska 6 Department of Environmental Conservation which appear to be 7 required for this activity and would have direct bearing on the 8 issuance or denial of an aquifer exemption. 9 First, a waste water disposal permit appears to be 10 required pursuant to 18 AAC 72.210 which requires a permit for II the disposal of nondomestic waste water. Nondomestic waste water 12 is defined as "liquid or water-carried wastes resulting from a 13 manufacturing or production enterprise; industrial establishment; 14 development or natural resources; or other wastes which are 15 waterborne or in a liquid state." It has been our experience in 16 other ADEC regions in Alaska that applications for UIC permits and aquifer exemptions are filed concurrently with ADEC waste water disposal permit applications. This was not done in this case. Also, a solid waste disposal permit may be required if solids are to separated from the fluids and disposed of separately. It is known that a reserve pit existing at the D-l well site was closed out in 1981. If Unocal anticipates reentry or reuse of this pit, this should be indicated in the R & R COURT REPORTERS 810 N STREET, SUITE 101 277-0572 - 277-0573 1007 W. 3RD AVENUE 272-7515 509W.3RDAVENUE 277-8543 ANCHORAGE, ALASKA 99501 -~ - -.- ."-'"" 9 application. If Unocal will be handling API separator bottoms or other listed wastes under RCRA at this facility, then the 2 procedures for hazardous wastes under RCRA, the Resource 3 Conservation Recovery Act, may be required. 4 Two, Unocal and/or this Commission have apparently failed 5 to notify, or had as of the time that the application was made 6 and these comments were prepared, failed to notify the Office of 7 Management and Budget, Department of Governmental Coordination of 8 this application so that DGC can do their duty and render a 9 federal consistency determination under 16 USC 1456; and, two, a 10 conclusive state consistency determination as required by Alaska 11 Statutes Title 44, Chapter 19.145(a)(11) whenever an application 12 requires permits, leases or authorizations from two or more 13 governmental agencies. This permit cannot be granted and so 14 until such determinations are made. 15 Three, Section 307(c)(3) of the Coastal Zone Management 16 Act of 1972, as amended by 16 USC 1456(c)(3), requires a 17 certification that activity affecting land or water uses in the 18 Coastal Zone complies with the Alaska Coastal Management Program. 19 A determination of consistency with the Matanuska-Susitna Borough 20 Coastal Management Program is also required pursuant to Alaska 21 Statutes Title 46. 22 Unocal and/or this Agency hav~ -- had apparently as of 23 the time these comments were prepared, apparently failed to 24 notify the Matanuska-Susitna Borough or the Office of Management 25 R & R COURT REPORTERS 810NSTREET,SUITE 101 277-0572 - 277-0573 509 W. 3RD AVENUE 277-8543 1007 W. 3RD AVENUE 272-7515 ANCHORAGE, ALASKA 99501 ·_~ e-....-' 10 ~??' and Budget, DGC, of the proposed injection well activity, and as a result, have failed to receive a determination of consistency 2 for this activity. The proposed activity is within the Mat-Su 3 coastal zone as shown on shown on Tyonek map number 89 of the 4 Alaska Coastal ...... 5 MR. CHATTERTON: Mr. Weiner, may I -- may I 6 interrupt you for a moment? 7 8 MR. WEINER: Certainly. MR. CHATTERTON: This is very good. This -- this 9 hearing right now is on the application for exempting an aquifer. 10 No -- no construction or anything like that is going on. Weill 11 - weill -- does that fit -- do you wish to make this -- as you 12 know, we follow with another hearing that 13 ~~' MR. WEINER: Absolutely. 14 MR. CHATTERTON: . . . . . that ...... 15 16 17 18 will apply to 19 20 21 22 23 save some time 24 25 J~. MR. WEINER: Many of ..... MR. CHATTERTON: Will MR. WEINER: ..... many of my comments will -- MR. CHATTERTON: Will also apply to that? MR. WEINER: ..... also apply there. MR. CHATTERTON: Okay. MR. WEINER: And perhaps at that point we can MR. CHATTERTON: All right. R Be R COURT REPORTERS 810N STREET, SUITE 101 277-0572 - 277-0573 509 We 3RD AVENUE 277-8543 1007 We 3RD AVENUE 272-7515 ANCHORAGE, ALASKA 99501 -=' 2 3 4 5 6 7 8 9 10 11 12 13 14 ._~ 11 MR. WEINER: ..... by -- by referring to the comments made MR. CHATTERTON: Okay. MR. WEINER: ..... at this juncture. MR. CHATTERTON: Very fine. Proceed. Thank you. MR. WEINER: I was referring to Tyonek Map 89 of the Coastal Zone -- Alaska Coastal Zone Boundaries which show that well D-l falls within the Coastal Zone Management Program or the Alaska Coastal Zone Management Program. Number four, City Service -- Cities Service Company, apparently a predecessor corporation to Unocal, apparently had a fill permit from the Army Corp of Engineers for the D-l pad, but our understanding is that Unocal has failed to transfer that fill permit for the Lewis River D-l paid from Cities Service to 15 Unocal. Unocal as opposed to Cities Service Company must apply 16 for and receive a transfer of this permit before an aquifer 17 exemption or a UIC permit can be issued. 18 Five, public notice issues. AOGCC's, this Commission's, 19 October 7, 1985, application for primary enforcement 20 responsibility requires this Commission to allow, quote, "any 21 interested person" to be heard at a hearing. However, the public 22 notice published by this Commission for this permit limited the 23 opportunity to protest and request a public hearing to those, 24 quote, "persons who may be harmed if the requested order is 25 issued. II This language unlawfully restricts public access. By R & R COURT REPORTERS 810 N STREET, SUITE 101 277-0572 - 277-0573 509W.3RDAVENUE 277-8543 1007W.3RDAVENUE 272-7515 ANCHORAGE, ALASKA 99501 ........'2"~ ---~ "~ ~ ..,- 12 discouraging public participation rather than encouraging it, 2 this permit application (sic) may also violate both state and 3 federal law, so we take specific exception to the manner of the 4 notice. 5 Actions taken by the Alaska Oil and GAs Commission are in 6 the form of orders rather than permits, although permits are 7 specifically referred to throughout the federal and state 8 statutes. Orders being a direction of a court, they are 9 inappropriate when this Commission is acting as an administrative 10 body as opposed to a judicial body, and it may be more 11 appropriate in the future for the Commission to prepare permits 12 rather than issue orders. The orders do not list specific 13 requirements for compliance as permits would. This is a 14 violation of the intent, if not the legal requirements, of the 15 urc program. 16 Time periods. When administered by the EPA prior to June 17 19, 1986, before this Commission received primacy, the urc IS program required a 3D-day public notice period for comments 19 and/or requests for a public hearing. When primary enforcement 20 responsibility was granted to this Commission in June of '86, 21 public notice periods were reduced to 15 days. Reduction of the 22 public comment period in this manner severely impacts the ability 23 of the public to participate in the permitting process in a state 24 the size of Alaska with its geographical immensity and 25 impediments to communication. It may also violate guidelines R & R COURT REPORTERS 810N STREET, SUITE 101 277-0572 - 277-0573 509W.3RDAVENUE 277-8543 1007 W. 3RD AVENUE 272-7515 ANCHORAGE, ALASKA 99501 - -:-~ ~- 13 found in EPA's Guidance for State Submission under Section 1425 2 of the Safe Drinking Water Act, which requires notice that is, 3 quote, "adequate to bring the matter to the attention of 4 interested parties and, in particular, the public in the area of 5 the proposed injection." And that's found at Section 5.6. So 6 that we would request that in the future this Commission give the 7 public 30 days as opposed to 15 days notice. 8 Residents of remote sections of the state such as those 9 adjacent to the Lewis River Field may never become aware of these 10 actions prior to the expiration of the public comment period. In 11 the specific case of the Lewis River permit request, it is 12 doubtful that the residents of Tyonek Village, the Grants area, 13 the Susitna Flats area, or the Alexander area have been informed 14 of this application or have been provided with a reasonable 15 opportunity to comment. The Commission should renotice this 16 application for an additional 15 or 30 days and make a concerted 17 effort to provide notice to and solicit comments from those 18 citizens who would be most affected by this action. 19 Procedural issues. This Commission has not established a 20 defined procedure for -- for applying for an aquifer exemption, 21 thus determination of the progress toward issuance or denial of 22 an application cannot be determined by reference to the materials 23 in the public record. For example, if this Commission were to 24 determine that the application lacked technical documentation 25 from Unocal, interested parties such as Trustees for Alaska or R & R COURT REPORTERS 8 0 N STREET, SUITE 101 277-0572 - 277-0573 509 W. 3RDAVENUE 277-8543 1007W.3RDAVENUE 272-75 5 ANCHORAGE, ALASKA 99501 .,-~- '---~ ....-~_. 14 the Alaska Center for the Environment would have no way of 2 knowing that such information had been requested or was available 3 for review. This Commission's procedures should be revised to 4 incorporate forms and procedures to provide for a rational and 5 trackable permitting process. The forms and procedures should, 6 at a minimum, incorporate the following: 7 First, a standardized application form detailing the 8 information that must be provided by the applicant, such as 9 Unocal, before the application be can be considered complete. 10 Two, a formal determination of application completeness 11 by this Commission and a notification to the applicant and the 12 public of this determination. Conversely, if an application is 13 found to be incomplete, this should also be formally conveyed to 14 the applicant and interested parties in writing, along with a 15 definition of what additional or a description of what additional 16 materials are required to complete the application. 17 Four -- Three, issuance of a draft permit by this 18 commission and public notice of this action should be 19 incorporated into the standard procedures of AOGCC, along with a 20 request for public comment on the draft permit. These are 21 procedures, by the way, that are found with numerous other agencies in both the federal and state level and give the public an adequate opportunity to comment and provide additional 22 23 24 information to the Commission that could be useful. 25 Issuance of a fact sheet accompanying the draft permit R & R COURT REPORTERS 810N STREET, SUITE 101 277-0572 - 277-0573 509 W. 3RD AVENUE 277-8543 1007 W. 3RD AVENUE 272-7515 ANCHORAGE, ALASKA 99501 L~~ 15 16 17 18 19 20 21 22 23 24 25 -.~- '~ 15 describing the proposed project to assist members of the public 2 in understanding the project and the very important issues involved. 3 4 Five, formal written guidelines for evaluation of an 5 aquifer exemption by your staff. 6 Six, proper public notice in accordance with the Alaska 7 Statutes and the EPA guidance -- guidelines soliciting comment on 8 this permit applications, issues which I have raised previously. 9 Also, a proper format to include responses to public 10 comment in the permit record. 11 Also, proper public notice in accordance with Alaska 12 Statutes of final AOGCC action on the requested permit, including 13 procedures to appeal the action. 14 And finally, a permit form which would be issued to the successful applicant detailing his entitlements, limitations, monitoring requirements, and reporting requirements as opposed to the brief order as I have discussed previously. Seven, the land on which the Lewis River D-1 well will be drilled is not included in the Lewis River Unit. AOGCC's authority under the Alaska statutes, Title 31.05.027 and 180(p) to issue aquifer exemptions for activity outside of an existing oil and gas unit is highly questionable. And the application itself contains a map, attached after page five of the application, which ..:.. MR. SMITH: Pardon me, Mr. Weiner? R & R COURT REPORTERS 810 N STREET, SUITE 101 277-0572 - 277-0573 509W.3RDAVENUE 277-8543 1007W.3RDAVENUE 272-7515 ANCHORAGE, ALASKA 99501 l3 89, the Tyonek ""-=" l4 for exhibit? l5 l6 '- 19 20 2l 22 23 24 25 "'-::~¡,,? ~-- '''"-'' 16 MR. WEINER: Um-hm? 2 MR. SMITH: Do you intend to make this first map 3 you spoke of and that map youlre speaking of not exhibits to your 4 testimony? 5 MR. WEINER: They probably don't have to be, 6 because they're already -- they were already included in the 7 record when Unocal made the application part of the record. I'd 8 be happy to do so. 9 MR. SMITH: Well, it's up to you. to MR. WEINER: Actually, yes, it was pointed out II that this was not part of the -- of the application. At this l2 time maybe it would be appropriate for us to add Tyonek Number Number 89 map, to the record and have it marked MR. SMITH: That will be Exhibit A. MR. CHATTERTON: Okay. Thanks. Duly noted, and l7 Exhibit A I guess is what we Ire referring to, is made part of the l8 record. MR. WEINER: Thank you, Commissioners. The map I'm referring to now is part of the Unocal application, and it shows the site of the Lewis River D-1 well, and also shows that the well is outside of the Lewis River unit. Moreover, neither oil nor gas was found at Lewis River in commercial quantities, and well D-1 was plugged and abandoned on October 3rd, 1981. The lease on this land will expire after ten R & R COURT REPORTERS 810N STREET, SUITE 101 277-0572 - 277-0573 509W.3RDAVENUE 277-8543 1007W.3RDAVENUE 272-7515 ANCHORAGE, ALASKA 99501 ~- '-- 17 years pursuant to Alaska Statute 38.05.180, and we believe that 2 this lease as well will expire in the next year or two, because 3 leases cannot be extended unless, quote, "oil or gas is produced 4 in paying quantities. II As a result, this underground injection 5 permit cannot be granted for a period of more than a year or two, 6 past the time when that -- Unocalfs lease would normally expire. 7 These issues must be resolved prior to the issuance of an 8 aquifer exemption on this land. 9 Eight. Some of the injection fluids listed by Unocal 10 pursuant to 20 AAC 25.252(c)(7) are ineligible for disposal into 11 Class Two wells. EPA has provided specific guidance on the 12 fluids eligible for disposal into Class Two wells, and these do 13 not include such fluids as equip- -- as equipment wash water or 14 other liquids not brought to the surface in conjunction with oil 15 and gas production. 16 Nine. Unocal has failed to demonstrate that the aquifers 17 below 1300 feet below ground level contain more than 3,000 parts 18 per million total dissolved solids. Such proof must provided by 19 a sample of the formulation fluids analyzed in accordance with 40 20 CFR 136 using method 209 B, attached. 21 And I believe our technical advisor will be going into 22 this in more detail during his testimony, is that correct? 23 Ten. The Governor's Office is required to adopt a 24 wellhead project- -- protection program pursuant to Section 1428 25 of the Safe Drinking Water Act. This program must be in effect R & R COURT REPORTERS 810NSTREET,SUITE 101 277-0572 - 277-0573 509 W. 3RDAVENUE 277-8543 1007 W. 3RD AVENUE 272-7515 ANCHORAGE, ALASKA 99501 ~.--~ 13 ........~ 14 15 16 17 18 19 20 21 22 23 24 25 -- .--- 18 by June 19, 1989, and will protect, quote, "the surface and 2 subsurface area surrounding a water well or well field," end 3 quote. Since the applicant has stated that there is a fresh 4 water aquifer over 1,000 feet thick which lies immediately 5 beneath the surface in the Lewis River Field area, and we do not 6 know the size of this aquifer, this exemption should not be 7 granted until the studies required by Section 1428 are completed. 8 Otherwise, the public may be foreclosed from ever using this 9 known fresh water aquifer or the aquifer proposed proposed for 10 waste disposal as a drinking water supply or for any other use. 11 11. Similarly, a demonstration program to protect sole 12 source aquifers must be implemented to protect critical aquifers pursuant to Section 1427 of the Safe Drinking Water Act. Since the Matanuska-Susitna Borough, or other state agencies, may identify the aquifers below Lewis River -- River as critical aquifers, AOGCC should not grant this exemption until such time as the other interested municipal or local governments have had a specific opportunity to comment upon the impact of contamination of these aquifers. And I appreciate the Commissioners' time, and that concludes my comments at this stage of the proceeding. MR. CHATTERTON: Thank you, sir. You have -- you were also going to testify? MR. DIZOTELL: Yes. MR. SMITH: Could I ask one question here? R & R COURT REPORTERS 810N STREET, SUITE 101 277-0572 - 277-0573 509W.3RDAVENUE 277-8543 1007 W. 3RD AVENUE 272-7515 ANCHORAGE, ALASKA 99501 13 ...~~ 14 15 16 17 18 19 20 21 22 23 24 25 ~- -- 19 MR. CHATTERTON: Sure, you bet. 2 MR. SMITH: Do you plan to submit your -- a copy 3 to us of your testimony you just. ....? 4 MR. WEINER: What I propose to do is submit a 5 final copy later this afternoon. These are my 6 MR. SMITH: Okay. 7 MR. WEINER: oral comments, and I will make 8 sure that the Commissioners and anyone else you suggest gets a 9 final copy of these. 10 MR. CHATTERTON: Mr. Weiner, it would be helpful 11 to Meredith I suspect for her when she writes up -- I I 12 realize this -- you don't wish to call this official, MR. WEINER: Correct. MR. CHATTERTON: but it -- it really is, because you've put it on the microphone MR. WEINER: Um-hm. MR. CHATTERTON: okay? To -- If you have a copy that you -- and we can make a copy, give to her to -- to make it easier for her, MR. WEINER: I'd be happy to. MR. CHATTERTON: ..... we'd appreciate it. MR. WEINER: I'd be happy to provide you with that. MR. CHATTERTON: Okay. Very good. Okay. Any-- any other questions, Lonnie? R & R COURT REPORTERS 810N STREET, SUITE 101 277-0572 - 277-0573 509W.3RDAVENUE 277-8543 1007W.3RDAVENUE 272-7515 ANCHORAGE, ALASKA 99501 .~ 9 10 11 12 13 '-~:-=-./ 14 15 16 17 18 19 20 21 22 ....~ .- '~ 20 MR. SMITH: No, go ahead. 2 MR. CHATTERTON: Proceed. 3 MR. DIZOTELL: My name is Robert Dizotell. I'm 4 employed by Trustees for Alaska as a technical advisor. I will 5 be presenting a short summation of technical comments on the 6 aquifer exemption application. 7 Unocal has estimated equivalent salinity in parts per 8 million sodium chloride for the formation fluids adjacent to the D-l well by extrapolating from electric log resistivity data. There are several problems with this approach. The fluid parameter that is of concern is TDS, total dissolved solids, not salinity. These will be significantly different values. Total dissolved solids are defined in 40 CFR 146.4 and are determined by EPA method 209 B as listed in 40 CFR 136. A copy of this sample procedure is attached for reference. A formation water sample will -- will be required for this determination in accordance with 40 CFR 147. And I'll submit a copy of this procedure with some testimony (ph) that's attached to it as Exhibit B. MR. SMITH: Okay. We'll call it Exhibit B. MR. DIZOTELL: C. The resistivity reading may be 23 affected by well completion fluids which may have migrated a long 24 distance from the well bore. 25 D. The temperature gradient calculated by Unocal may be R & R COURT REPORTERS 810N STREET, SUITE 101 277-0572 - 277-0573 509 W. 3RD AVENUE 277-8543 1007W.3RDAVENUE 272-7515 ANCHORAGE, ALASKA 99501 - '-' 21 .-- incorrect. The 35 degree assumption for the surface may be 2 correct for the ambient air temperature, but certainly would not 3 be correct for the subsurface groundwaters. We suspect that 4 these waters would be in the 45 to 50 degree range at a minimum. 5 Two. Unocal's geologic data for a freshwater aquifer 6 exemption is replete with wording such as, "In the absence of 7 reliable laboratory water analysis data," "assumed to be the best 8 approximation," and "when corrected for -- to formation 9 temperature, can be used for estimate." It is rather obvious 10 that this is an approximation of the aquifer fluid properties. 11 Three. It is question- -- well, Unocal assumes that the 12 aquifers below 1300 feet beneath Lewis River well D-1 cannot ever 13 be utilized as a drinking water aquifer for reasons of economics 14 and practicality. Unocal has not presented any proof of this 15 assertion in the form of engineering or economic studies. The 16 burden of such proof rests upon the applicant. 17 Six, or four. Unocal has not addressed the issue of 18 casing cement- -- cementing as required by 20 AAC 25.25(b) 19 252(b). The integrity of the cementing of this well is 20 particularly critical between 1190 feet and 1270 feet of measured 21 depth. Cement bond logs performed on this well begin at 22 approximately 1330 feet. Unocal must demonstrate the integrity 23 of the cement between 1330 feet and the surface. 24 Unocal has not specifically identified the confining 25 formation for this well. Unocal describes the formations between R & R COURT REPORTERS 810NSTREET,SUITE 101 277-0572 - 277-0573 509 W. 3RD AVENUE 277-8543 1007W.3RDAVENUE 272-7515 ANCHORAGE, ALASKA 99501 ~-~/ -~ 20 21 22 23 24 25 ~-~/ <- '-' 22 1193 feet and 1200 -- 1300 feet below the surface as a 2 permeability barrier, but do not designate it as the confining 3 formation for the injected fluid. Unocal must identify and 4 detail the lithologic characteristics of the confining 5 formations, both upper and lower, before either an aquifer 6 exemption of a UIe permit can be issued. 7 Porosity for this well is listed by Unocal at 18%. 8 Porosity is used as a factor in Unocal equations used to derive 9 salinity. The required injection pressure may be 1500 psi and 10 the average disposal rate is proposed to be 75 barrels per day. 11 A surface pressure of 1500 psi will result in a downhole pressure 12 of between 2800 and 3,000 psi at 3,000 feet. A rate of 75 13 barrels per day is about two and a quarter gallons per minute. 14 If this formation does indeed have a porosity of 18%, this 15 disposal -- this disposal rate should be capable of entering the 16 formation with little or no surface pressure. The reason for the 17 excessive back pressure must be explained by Unocal and how this 18 injection pressure is related to formation porosity and disposal 19 rate. Unocal's characterization of the aquifers beneath the Lewis River well D-1 is incomplete. Additional data needed includes definition of the aquifer charge/recharge mechanism, definition of the aquifer drainage mechanism, definition of the movements through and within the aquifer. May I ask a question off the record? R & R COURT REPORTERS 8' 0 N STREET, SUITE 101 277-0572 - 277-0573 509W.3RDAVENUE 277-8543 1007 W. 3RD AVENUE 272-7515 ANCHORAGE, ALASKA 99501 - 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 ~~ L~_ .---~ 23 MR. CHATTERTON: Yeah, we -- we -- yeah. Off the record, please? (Off record) (On record) MR. DIZOTELL: That is the completion of my testimony on the aquifer exemption. MR. CHATTERTON: All right. Mr. Weiner, while we were off the record, why, you indicated that you might wish to add a little bit more to your direct testimony..... MR. WEINER: Yes. MR. CHATTERTON: earlier, and we're happy ..... to oblige you. MR. WEINER: Thank you, Commissioner. There is some question as to whether a state commission has the legal authority to -- to waive the requirement for a laboratory analysis of a formation water sample. UIC program primacy conveyed under Section 1425 of the Safe Drinking Water Act applies to UIC Class Two permits, but does not appear to convey the authority to grant aquifer exemptions. It appears that such authority is reserved to the EPA. Item 13 of the signed memorandum of agreement between 22 AOGCC and EPA states that the aquifer exemptions will be approved 23 or disapproved by EPA as opposed to the State Commission within 24 14 days of the EPA being notified by AOGCC. 25 I think that concludes my testimony, too. R & R COURT REPORTERS 810NSTREET,SUITE 101 277-0572 - 277-0573 509W.3RDAVENUE 277-8543 1007W.3RDAVENUE 272-7515 ANCHORAGE, ALASKA 99501 ._~ --= "-' 24 -~~' MR. CHATTERTON: Thank you. Thank you, 2 Mr. Weiner. Bob, go ahead? 3 MR. DIZOTELL: I'm done. 4 MR. CHATTERTON: That concludes your testimony? 5 Okay. 6 Let me refer to my -- my guideline basically referring to 7 20 AAC 25.540, and the applicant will be asked to present 8 testimony, and they referred only to their application as being 9 their testimony, so they offered none. And people wishing to -- 10 okay. A person -- we allowed you the right to submit a written 11 statement and testify into the record. Okay. 12 Lonnie, do you have any questions of -- of these 13 gentlemen? ..-~. 14 MR. SMITH: No, I don't. I donlt 15 MR. CHATTERTON: I do not either. Are there any 16 questions to be asked from the -- from anybody present here? If 17 so, why I'd like to see them up before me and 1111 see if they're 18 germane to the issue. Yes? 19 MR. ROBERTS: Mr. -- Mr. Chatterton, ...... 20 MR. SMITH: Speak up. 21 MR. ROBERTS: Excuse me. I 1m curious about 22 Unocalls ability to respond to the comments from this hearing, or 23 respond. Is that going to be focused back from the AOGCC to 24 Unocal to answer these questions which the AOGCC may have 25 concerning the comments that are -- have been given in this '-".r~ R & R COURT REPORTERS 810 N STREET, SUITE 101 277-0572 - 277-0573 509 W. 3RD AVENUE 277-8543 1007 W. 3RD AVENUE 272-7515 ANCHORAGE, ALASKA 99501 ";;;~ =:~' ~.._~ ~ 25 hearing? 2 MR. CHATTERTON: Well, anything that you wish to 3 testify to, why I -- I don't like the idea of -- of entertaining 4 rebuttal, but if there are points that you chose to testify on, 5 why we will provide you the opportunity to testify. But if it's 6 questions that you're asking of anybody that has testified, then 7 they will be directed through the chair. I -- I might have 8 I'm puzzled and at a loss as to -- as to how to proceed on this, 9 to be very truthful with you. 10 MR. ROBERTS: Yes, sir. Could we request a 11 recess for a short time to -- so that we can discuss this within 12 Unocal? 13 MR. CHATTERTON: Pardon? 14 MR. ROBERTS: Can we request a recess for a short 15 time to discuss how we wish to proceed on this matter? 16 MR. CHATTERTON: Certainly, yes. Off the record, 17 please. 18 (Off record) 19 (On record) 20 MR. CHATTERTON: We're back on the record, and 21 while we were off the record, we discussed with the principals at 22 -- in this hearing the procedural steps to follow from here on 23 out, and in summary, why we decided to -- it would be most 24 helpful to the Commission and its deliberations, to keep the 25 record open following the close of this hearing for two weeks. R & R COURT REPORTERS 810NSTREET, SUITE 101 277-0572 - 277-0573 509W.3RDAVENUE 277-8543 1007 W. 3RD AVENUE 272-7515 ANCHORAGE, ALASKA 9950 I 10 11 12 13 -~ 14 15 16 17 18 19 20 21 22 23 24 25 '~~ ~~_. .-- 26 And I guess we better put a date so we don't get confused about 2 working days and everything else. Let's -- let's -- we'll -- 3 let's set a date, 27th .... 4 MR. SMITH: The 27th. We're at the 13th. 27th, 5 Friday. 6 MR. CHATTERTON: Why don't we -- why don't we 7 make it Monday the ..... 8 MR. SMITH: Prior to Monday at 8:00 a.m., 9 or ..... MR. CHATTERTON: ..... Monday, the -- well, Monday at 5:00 o'clock, the 30th. We'll keep the record open then for the filing of written comments which will be beneficial to the Commission in its deliberations until 5:00 p.m. January 30th, 1989. It was mutually agreed to that the applicant would file their comments within a matter of one week's time, and that the - - any members of the public that so chose could file their comments within -- by this time on the 30th of -- of the month. We did request Trustees for Alaska to make their December 28th, 1988, letter to Commissioner Lonnie Smith, a copy to the Union Oil Company of California, part of the record of this hearing, and is that correct, Mr. Weiner? MR. WEINER: (Nods head affirmative) MR. CHATTERTON: And he nods assent to that. MR. SMITH: Well, let's go -- on the record then, R & R COURT REPORTERS 810N STREET, SUITE 101 277-0572 - 277-0573 509W.3RDAVENUE 277-8543 1007 W. 3RD AVENUE 272-7515 ANCHORAGE, ALASKA 99501 10 11 12 13 .=-~ 14 --- ..------ ~' 27 let's make that Exhibit C? 2 MR. CHATTERTON: And we will call that Exhibit C, 3 the December 28th, 1988, letter, Trustees to Commissioner Smith. 4 Are there any -- any -- does anyone wish to make any 5 further comments or -- or statements? 6 MS. LIB ENS ON: I would MR. R-OBERTS: Yes, sir, Mr. Chatterton, I'd like to indicate for the record that Unocal will also submit their 7 8 9 comments to the Alaska Center for the Environment for their consideration after the week's period, at -- at the week's period, as part of the record. MR. CHATTERTON: Thank you. I think that is probably very appropriate. MS. LIBENSON: I'd like to testify. Commiss- 15 Commissioner, my name is Sue Libenson, and I'm the executive 16 director of the Alaska Center for the Environment. 17 And my comments today will be fairly brief. I suppórt 18 many of the comments that Trustees for Alaska has brought to you 19 this morning both in terms of procedural questions concerning 20 application and granting of these type of orders, and some of the 21 technical issues that were raised concerning the establishment of 22 the size of the aquifer and the safety of potential drinking 23 water sources. 24 And the first thing I would like to point out about. this 25 meeting or hearing is that I think there has been a lack of R & R COURT REPORTERS 810NSTREET,SUITE 101 277-0572 - 277-0573 509W.3RDAVENUE 277-8543 1007 W. 3RD AVENUE 272-7515 ANCHORAGE, ALASKA 99501 -,- ~-~~ 14 15 16 17 18 19 ---. --.I'i!!!!IP'--_~ '-- 28 public involvement and oversight on the general issue of aquifer 2 exemptions, and I donrt think I think this is something that 3 demands in the future further involvement on the part of the 4 public as this is a fairly important step in seeing oil and gas 5 development go through, and we are talking about drinking water. 6 And I think it's unfortunate that the applicant as 7 Mr. Dizotell has pointed out has used some fairly loose data in - 8 - in making their statement that drinking water will not be 9 affected. And we only need to look at the city in which werre 10 holding this meeting. Anchorage has only been in existence as a 11 major population center for the last 40 years. Certainly 100 12 years ago no one would have thought of this as being a 13 potentially important place to worry about ground water. And I just want to make that clear to the record, that I think we need to consider potential drinking water sources even in areas which are not heavily populated at this time. And with that in mind, I would like to reiterate the concerns of Trustees that Irm not satisfied with the data given in terms that -- that attempts to show that drinking water is not 20 at risk and that -- that the water in question is not of drinking 21 water quality. 22 Again, there were questions raised about the size of the 23 aquifer has not yet been to my satisfaction adequately 24 determined. We do not have information on total dissolved 25 solids, which are the basis on which drinking water is evaluated. R & R COURT REPORTERS 810 N STREET, SUITE 101 277-0572 - 277-0573 509 W. 3RD AVENUE 277-8543 1007 W. 3RD AVENUE 272-7515 ANCHORAGE, ALASKA 99501 -~.~c -- 29 .,,~ We don't have information on charge and recharge mechanisms, 2 drainage mechanisms for this aquifer, or movement of fluids 3 within this aquifer. And this is again especially of concern in 4 this aquifer where as Mr. Dizotell pointed out there is a high 5 porosity, and it appears to be that migration of wastes that 6 could be injected under -- with this exemption could easily enter 7 this -- what I would consider a potential drinking water aquifer 8 until it's been satisfactorily demonstrated that it's not 9 potentially drinking water quality. 10 So these are some of the major concerns that I have, and 11 I think we need only to look across Cook Inlet to the Kenai 12 Peninsula where we've had oil and gas development for a number of 13 years, and daily we discover new problems with drinking water on 14 the Kenai Peninsula, and -- and so I -- I really would request 15 that the Commission take a long, hard look at the data and -- and 16 make sure that you have enough information to determine whether 17 or not we are talking about potential drinking water and whether 18 or not the aquifer in this formation -- whether any waste 19 potentially injected into this formation under this exemption 20 would potentially enter a drinking -- a drinking water aquifer. 21 Some of the other points that I think are germane to this 22 permit and then also germane to just the general process, I would 23 also like to reiterate this is a fairly technical area for the 24 public to enter. It's not easy to jump into discussions on well 25 casing and porosity and dissolved solids without a lot of R & R COURT REPORTERS 810N STREET, SUITE 101 277-0572 - 277-0573 509W.3RDAVENUE 277-8543 1007 W. 3RDAVENUE 272-7515 ANCHORAGE, ALASKA 99501 "~"-~ c.__ 30 technical advice, and it would be helpful for the general public 2 to some kind of fact sheet describing in layman's terms what 3 what is at risk, what are the variables that -- of concern. 4 And I think if more people of the public were aware of 5 the implications of an aquifer exemption, you would see more 6 public involvement at these hearings. I know that this is 7 probably an usual level of involvement for an exemption. 8 So I would like to reiterate some of the procedural 9 issues that Trustees brought before you this morning, and just to 10 -- to reiterate that there are concerns concerning drinking water 11 and aquifers in Alaska. We're heading towards -- in other areas 12 of the state towards a groundwater program, towards -- we're 13 we're seeing more and more money being expended on testing 14 ground- -- contaminated groundwater in existing oil and gas 15 areas, and and more and more public concern over groundwater 16 quality, so I think it would help the Commission -- you would see 17 a lot more public input on the part of citizens with an improved 18 public participation program. 19 And those are my comments. Thank you. 20 MR. CHATTERTON: Thank you very much. Are there 21 any other people wishing to make any statements or offer the 22 chair some -- any questions that they -- that we can pass on? 23 I think the chair would like to make one statement. I 24 think generally everyone recognizes that the Safe Drinking Water 25 Program of -- administered by EPA includes in part 147 that -- "'-~- R & R COURT REPORTERS 810N STREET, SUITE 101 277-0572 - 277-0573 509W.3RDAVENUE 277-8543 1007W.3RDAVENUE 272-7515 ANCHORAGE, ALASKA 99501 -- '-- 31 ....-;~.... that this agency administer their program in the State of Alaska. 2 There was one -- subject to one exclusion in 3 administering, and that is the exemption of aquifers, so we act 4 as a clearing house, but we do not have the right or the 5 authority to exempt any aquifer. 6 The results of this hearing, of course, is going is 7 being watched carefully by EPA, and on -- and it's even being 8 monitored by an EPA representative. And I'm sure that they'll 9 take to heart the hearing record before they make a determination 10 on any aquifer exemption. 11 While we're here I just wanted -- that's -- that's my 12 understanding of the procedures anyway. And and we will -- 13 we're -- at least we're going to go along on on that basis. 14 Are there any other things to come before us on this 15 matter? Well, the time is roughly 10:18, and we'll adjourn this 16 session on the aquifer exemption application of Union's hearing 17 and keeping the record open until 5:00 p.m. January the 30th, 18 1989, for the filing of additional written comments and 19 statements. 20 Without further adieu I guess we're through. 21 (END OF PROCEEDINGS) 22 23 24 25 R & R COURT REPORTERS 810NSTREET,SUITE 101 277-0572 - 277-0573 509W.3RDAVENUE 277-8543 1007W.3RDAVENUE 272-7515 ANCHORAGE, ALASKA 99501 11 12 13 --~. 14 15 -~ --~~~ -"= .~ 32 C E R T I F I CAT E 2 UNITED STATES OF AMERICA 5S. 3 STATE OF ALASKA 4 I, Meredith L. Downing, Notary Public in and for the State of Alaska, residing at Anchorage, Alaska, and Electronic Reporter for R & R Court Reporters, Inc., do hereby certify: That the annexed and foregoing Public Hearing was taken before me on the 13th day of January, 1989, commencing at the hour of 9:00 o'clock a.m., at the offices of the Alaska Oil and Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, Alaska, pursuant to Notice; That all witnesses, before examination, were duly sworn to testify to the truth, the whole truth, and nothing but the truth; 5 6 7 8 9 10 16 That this transcript, as heretofore annexed, is a true and correct transcription of the testimony given at said Public Hearing, taken by me and thereafter transcribed by me. That the original of the transcript has been lodged, as required with the Alaska Oil and Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, Alaska; That I am not a relative, employee or attorney of any of the parties, nor am I financially interested in this action. IN WITNESS WHEREOF, I have hereunto set my hand and affixed my seal this 17th day of January, 1989. 17 18 19 20 ,- ì SEA L j 23 24 25 R & R COURT REPORTERS 810N STREET, SUITE 101 509W.3RDAVENUE 1007W.3RDAVENUE 277-0572 - 277-0573 277-8543 272-7515 ANCHORAGE, ALASKA 99501 #5 '-.'iI~ 4&"L/C #,,~~/..vc:;;: /-/3-ff'i /.'<9ð_ ß: ~Æ7(;?/S- /fí v~ ¿g~ l), I .4 ~¿P-A/' b,.¡ A/ C ¿:- J , (D ~ '-.\ ··L Á-- Ô Vl V\ \ f ','- j t/tA. Y \ C )1 A 7 {' t-f.A Tf Y Ii 'j·u ^i Ç-fEueVl R ~{i~v g )O_I'y t: - (JJô Hd '-C(J (( b~ ~ Ò bl$;~ r- ~ e. Su../I J van 1,~!fébYh M f0Ji,J ~HM. tV\t\ ~~~~7 ~þ/~ ßowd uJ& ~¡e/ I Ct€~L// 'i~\.· ) 'j.'" · U IDJC)Y-J f.J,. ¡J.J)j..:J a ~ <) ~ q) ~ /Vl;kE N/:Nd€:Jrl- 5v"l ~#~ ~ ~'h~ ß vt, D J-S~1J, ( 4Ui;V A < -Î 41JLL~ /l/'~ Jj /) <:? /.. 1 rJì LG~~¡.-t.<-!.S"'<;!~ / L/ L,_,L '- / -, . CJiAJ t/~AVJj\) /(t~ h". A ô& ~ è' A-H-OI1A<lr CtV<~~' 06 C ~\ ....ì ,r. e'" .P ¿JUC9:LC E: ~ Ir ~ fh" d u v.... J1- ¡) Î\ () (!L,( UIJOC¡:)L ») ¿/4/oC#¿ ?f /V¿;J ?/9 ¿ 1}/l,&ha~¡Cfí ~:l Ct::ó/ ,{l. 0, b.LLI C . A\ /-" /."' /T /1 . Lj ''.c? L~:"---.d- A (;) Gee- /t-IL ~ ~~€/)vÌ'r(þ1.~ J 11r5~ s £'1" .Wcv.- ì rv5 ks ~. frl().s~ U l\LD C-IlL- #4 .--'-.. ,-,. -- Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: The application of UNOCAL for a Freshwater Aquifer Exemption - Lewis River Well D-l. UNOCAL by letter dated December 1, 1988, has requested a Freshwater Aquifer Exemption for formations occurring below 2300 feet measured depth in the Lewis River Well D-1 and lying within a % mile radius of the well. A person who may be harmed if the requested order is issued may file a written protest prior to December 29, 1988 with the Alaska Oil and Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, Alaska 99501, and request a hearing on the matter. If the protest is timely filed, and raises a substantial and material issue crucial to the Commission's determination, a hearing on the matter will be held at the above address at 9:00 a.m on January 13, 1989 in conformance with 20 AAC 25.540. If a hearing is to be held, interested parties may confirm this by calling the Commission's office, (907) 279-1433, after December 29, 1988. If no proper protest is filed, the Commission will consider the issuance of the order without a hearing. ,? /)0, ~ é~l- .JJ Lonnie ~:::~ Commissioner Alaska Oil & Gas Conservation Commission Published December 14, 1988 ~ ~ Re: The apptlcllilon of .'. I UNOCAL for I freshwater ,~ .' ' Aquifer Exemption ~. ~~ ~ .; .:!- '. " Lewl. River WeirD-I. I,' t . r;: " \ " , . . , I UNOCAl bV' lilter . dated De· :.~ (ember 1, 1988, has requested I :, Freshwater Aquifer Exemptlot1 : · for formations occurring below, , 2300 feet measured depth In the:· Lewis River Well 0-1 and Ivlng I . within I 1/~ mile radius of thl I . .well~,' ,,. .' '¡'.:" :1, ,;~, ::.: ~ " ;-,~'40.. , . ' I A person who mav be harmed..' 'If the requested or~er Is Issued.1 may file a written protest prior' to pecember 29, 1988 with the',' . Alaska 011 and Gas Conserve· ¡' ,I' lion Comml~lson, 3001 porcti· i :: pine Drive, Anchbrage, Alaska ~ . 99501, and reques' II hearing on '. the matter. If the prates' ..11 \ ' timely· flied , and ,6Ise,..:: , substantial and mllterla l$StJ~,' ~' crucial '0 the Commission's de. l ., . termlnitton, a heårlng on thi ~ . matter Will be held, a' .fhl t \ above address a' 9:00 ..m. on ~: ~ ,January 13,' 1989 In confor-·'. manee with 20 AAC 25.540. '". :' ~ hearing Is to be held, Interested· . parties may confirm this bV!. calling the Commission', office,' ~ (907) 219,1433, after Decembdr·' .:.. 29, 1988. If no proper protest Is ., J 'lied, the Commission will con· . . Ilder the tssuar1ce of the order ' i wlthou' · hea.rl~g.." r..'~ ", :.. j ...., t. ' /s/LOn'1fe' c. . Smith'· , . . , \ - : · , I'i·' ~ Commissioner, ' I', .. Alaska 011 & Gas Conservation. , . ,~omml~slon ". t' ': I : . ",' I.t:, .' j ..,' '. I ' ":;i : I is.' . 'Pub: December U, 1988 '~. . I !;. '~.:{ ,,~ I'" .: ,~/ AO: 08-5607 .~ ~II." r I ~ ~, ' '0 ~. ,0 ." ".: '. . . i ~ I.: Not.'ce of Public ~earlng . ~ I, ~ ¡,. STATE OF 'ALASKA ~" , ' Alaska 011 and Gas ,.," , .. t Conservation Commission' .:' ". . . ¡..... Pu bllc' 'Pr-- -'''-':,":.., -;'-,. .~'.'~',/Tr.:J? ~: . :'.t,,·, '!~ . i,~ Notices '... · ',,:j. 900 ~. ----- i , '. .~~ .-- STA1E OF ALASKA 'AD-VERTISING .. ORDER -rZ60l 19l433ALA F R o M Anchorage Daily News P. O. Box 149001 Anchorage, Alaska 99514-9001 T o p U B L I S H E R Alaska Oil & Gas Conservation Cnnmi asian 3001 Porcupine Drive Anchorage, AK. 99501 ADVERTISING ORDER NO. '~;jod-- AO.~'<>· - 08-5607 AGENCY CONTACT DATE OF A.O. Pat Oldenburg cenber 13, 1988 PHONE (907) 279-1433 DATES ADVERTISEMENT REQUIRED: Deœnber 14, 1988 SPECIAL INSTRUCTIONS: AFFIDAVIT OF PUBLICATION UNITED STATES OF AMERICA STATE OF Alaska ss Th i rd DIVISION. BEFORE ME, THE UNDERSIGNED, A NOTARY PUBLIC THIS DAY PERSONALLY APPEARED Cheryl A. Fletcher WHO, BEING FIRST DULY SWORN, ACCORDING TO LAW, SAYS THAT HE/SHE IS THE Legal Ad Assist OF Daily News PUBLISHED AT Anchora ge IN SAID DIVISION Thi rd AND STATE OF Al'ÅW THAT TH E ADVERTISEMENT, OF WHICH THE ANNEXED IS A TRUE COPY, WAS 14th PUBLISHED IN SAID PUBLICATION ON THE DAY OF December 19~ AND THEREAFTER FOR~ CONSECUTIVE DAYS, THE LAST PUBLICATION APPEARING ON THE 8~9_, AND THAT THE _ DAY OF RATE CHARGED THEREON IS NOT IN EXCESS OF THE RATE CHARGED PRIVATE INDIVIDUALS. ('it 0/10 () n ¿+ 0 0 tð~~ y - í) SUBSCRIBED AND ~WORN TO BEFORE ME TH _ Y OF Ua~ 9'i!6 TARY PUBLIC FOR STATE OF MY COMMISSION EXPIRES 02-901 (Rev. 6-85) PUBLISHER REMINDER- INVOICE MUST BE IN TRIPLICATE AND MUST REFERENCE THE ADVERTISING ORDER NUMBER. A CERTIFIED COpy OFTHIS AFFIDAVIT OF PUBLICATION MUST BE SUBMITTED WITH THE INVOICE. ATTACH PROOF OF PUBLICATION HERE. Notice of Public Hearing STATEO~'ALASKA AIëî$ka'~Oil~âni:l Gas , con5el"latlOl!Commi~ón ~ ~ " Rè:The application of UNOCAl fðrafréSbwater AqoiferEXen'lpfiOi1;; ..... .- Lewis RiVer:Well.'[H;· . iJNOcAL _bvl~er~cIât~ ~ : ..ceO'l~r 1,T98J,"1IåS:réquesteda ¡FreshwaterAqulfer Exemption i : forførmjltions'.øccurriógbeloW L -2311O'~feet;meàsur~(h.epth.:- in ffIt' . ; Lewis River Welt D-1a.nd IVing ¡ within a.1/4-mile radius-of ttre '.well. . - .." I~ .A.perSQl1Whomav behar~ if ¡the rèQuestedGrdet is,~ !. maVfile'awritten protestpiior I·_to aece"!ber29, 1988 V(lththe-. I Alaska Oil andGasConsenIa~ .tiotl·Commisison~ 3001.-PorCu-c ¡pine Drive, Anchoi'age-,A!ask-a !99501, and requ~a hearing on !thematter. ·Ifthe Pl"Gte.$t. iit I ~timeIY. flied , .·al\d;,r"-";~'á ,substantial. and mat"iafci~" 'cruc:lal:fo-theCommì"âiI's'~~, . . ter'miriatiòni'aheili:fW~òri.·ffli· nuitter will-be' held; -at _ffi8( above address at9iOOé;f;m.;-oit January 13,1989 in ionfor:· .manœwitÞ' 20M€' 25540:lf·1I .heârlngis1o:beheld,intètestécr parfiesmav-confirm:·this· by callin~the CòmmissilJlJ's:øffice; (907)2W-1433¡ -afterOecernber ;29, -1988.1f no ptpperprOtest is filed, the· ~omm,issiorr Will con- Ši~Jhlri$Wánc;eofthe-þrdër ~withoutahear:in~. '" . '/SlLónni.ç.$rnlth . Corrun.issioner'. . ..... .,'~ - AIa5k~9il & Gas CO;lI5erVation CornmrsSton . .. c. ;.; PUb: . qec,ember, 14,1988 AO:0&-~7 #3 GENERAL SITE DATA 10) sn. ldent No IG.I .1 I q.4 IÌ j r Ie:) IC"'HC) {JILl.cr k01 5 19 Site-Type G C D HIM P T W EJRelia::13- I cûj L M S collect..... dro,n. sinkholo. COftAKt..... multiplo. ponel.tunnel or. _II field chockod. unchKked. location not, ...ini....' _1I....h occurat. dUo PrOIe-ct r- -T~: ~ ~ County No '5-..__1 uL-L.l _. .l.i ¡ J L J Diltrict~ State~ Cor town) tORM NO 9-190.4- A :J)--¡ ~ -- R~cord~d by -",-~5-:þ.~____ latitude [!J :(p¡ : 18417EJ d.. LQn9itudeEl SITE NO. ~~ð /4 - 9 - 2 C6JY 3 - I us DEPT OF THE INTERIOR GEOLOGICAL SURVEY WATER ~ESOURCE5 DIVISION GROUND 'W.A TER SITE INVENTORY SITE SCHEDULE ._~ o jllo /87 I . Dote ¡ English Metric Units Check One AG Numb..- ~ TrwtUetion -u:;] Œ) 0 Hd. d.l.t.. ",odify. ...ifíH A=B()'S~LC)I M vE G ~ ~--~--- ~ Lat·Long :_ -=-, S ~ ¡ * : Accuracy L ~1 - : ! T M sec. 5 sec. 10 sec. Mtn : JI50;'5,6~19EJ d.. ...in LocatIon r· 1 M.,I' ' , 4, 11: '/:C L' .!fl~ '~~ß6~110IQCfo2JC.lß-D¿~3~-=-~--JX2J~~ ~;d '-3=5 F~tJ~~~) S .06 .T~ÛL1-J'L_~Ql~~' 1/4 1ft. 1/4 sectIon. township. ung!. rr.erld f~:--· --c----, -, ¡·-:/-3-3 ¡--O-:;' ~-----:..... ..:... . :...--:_ 1 . (~c~.*j Scale ~ _1_5...:'.i ~..l ¿Ü'-"-=--~ Local Number..1 2 = ~b- 01 L__i - --0J·;' Accuracy 0;=$ 0 _ ~_~ Aft,lud· . 16 I .:5~ . : r .1 Method of A ~ _: Measurement : , 7 ~ D C H K ø T OPO r Sett,n~ L:'9 0 ----- -- - T - ~--. ~ w * HydrologIc r ~~-=-:; /"" O~-O- Q- ~O-- -21·~ _ __ _______.________ UnIt iOWDCi '-- ~!...Lil _::J.... ...l..- ~ 1_--': DJtl of ForI! C(J!1S1rlJ{"tIU~'r '2 1 Conlplt'IIL\~' - -1.1 drprif'u..or . It'.."'. c1unll!"5. flat hilltop. sink. ,___amp. of!s.ho,e pEdlm~nt. hillside. terr,¡cE'. ur¡dulatlng. valle,.-. upldnd ch.",.-,tl flat dra.... w x z *, U,e of \&~ atrl B C .1' cond. b01rl'fI.: commt'rc,.I. d('watf"'. POWf'f. fire. domestic. Irrlga!IO~-.. med clna~_ Industria!, publ,c. rec!""eatlon. stock. InstItution. uncs!'~. desal. other i *. : 24- A U,e ,--, .---------- of ! 2 3 ~: A D E G Site ~-- ---- ----~------ ----------------.------, R T H ø M S U obsen- ITHn~. ad or. recharge. repress. téH. unuu:d. woth - ~as:E_ destn:"'r-e~ drain. gtc"'_- S~ISf!1iC. heat, I hf.-l 1'T1.d! V" drëwal at!oo. -- ----~ - - ----------- --------- -- - ---------........ - --~. D M N R T y l II H -------- ---~-- ------------ --- ---- - ------ -- - - -----~--- SüPp \ Source Q1<I"~ -------,------r-- Depth Data 2 9 ~ : * 1*' ~;~:::;~rUse r ~ 6~lE ~~:h Of~;i~-~~-ì~;:<¿:,-,-T*~ ~~:h of :-;;=~--·-T5 / -~ G):33=; :*1 Source '-- _--'----'-- sPcondar~ Water U,e 25· Water Level G~..l .¡Q3_L._L.lB -- - r·- -. -.---- -- .--- Method of Measurement ~_4~ C G i 3' = Ir3í I ,I /,1 Q.I :::1. *! Date Measured --.il.J ___~_ __ _ ' I' T'...)l : month day veer ,---- Z ; *. H L M R T v s .I,lan~_ u,lIbrited. ~Imat". press,ure. cahbrilted. geophysical. manometer, reported, 51eel, efectric, calibrated. o1her I.rllnt' ¡age preuure 1jJa!jle IGiS upe Ulpe electllC 1i1pe P S,te Status other ,---- T-:: I 37 = I 0 F G H ---1..____ _______ dr y. flowing, nSiJrby, nearby. flo...,"IJ reantly flOWH\g ø * R T V x z S nearby, to,elQn recently subsunce pumped Measuring 266~ Pornt ___ surf~e willer eft ects obstructIOn. pumpmg. recenUy. nearby, pumped pump'ng * Source of cr IL.~6_=T~ GcohydrologlC Data _._ ___ Measuring . 267= ,.- :z, Porn1 Date " ---. month , -""" """"",.------, Pump Used l2.5..:.L~ no .~ da..· ---. * , --0-.- yea~ OWNER IDENTIFICATION (11 ~GA Date of r;-s;-¡¡-1r 7-. / I ¡ / '0 r- r;1 Ownership ~'. )10 1\0 / 1 L I -"0 L.:J month day y.ar rn, 6 2 c ,-- -. ----. - -- n___ -- í-;' First L-__-----l_~~_! ___----1____ __ ~_ ~__~___~ D Mß odd. doloU. ...odify Lan EJ .'-li Ii I; IF.,--;I 1,-,E.låv.i:\riC>/J~ 163= .* Name: :----~ . . M,ddle Inltla! ~-~ 1 9 , = ' Assigner ____ __--L~~-------------.i____~~__---o..-___ -~--- OTHER Sll£ IDENTIFICATION NUMBERS III ~ [UA D MG dcirlf' rr.odd" r- . N~w CMd Sdmp R & T . Ident ~ I~ EJ Assigner 09-i.~1-~'Z/~~7¡ fLLZi_ ~-n_=--n~_-_ =~ Ident E:!J( )¡J ( nl¡\/~S'{) I, . Date of § VISII __l... n 1_ -1_ ~ _ SITE VISIT DATA 11! IR=186ß EI A D .drt_ dt';~'t' MGJ "'od,'-, 1 18 B ~ 1 G Namc of Person I í month / _ ___ ~__.c......l.. .._~~¿...¿._:~_ 1 ..1 doy year FIELD \\ATER OUAlITY MEASUREMENTS (1) IR=192 * 1 T·I ADM '.1 lieiC d~ 1'1~ modllv Nt",^" c.lrd- S.l~ì'- R thru 19S Date ~ / I ., ea' G Geohydro· i,9~ -~ ! * log'c UnIt ~..~---'--":"'----'--~~_--' / I d. . I m0nU'l i * I It 97 0 : Degree, C ' Boo 0 1 00 Temper.tur. . I I I I 1'97 < ¡ u Mhos ' I · ¡ , . ! *1 Other (STORETI B Paumeter Conductanct B 0 I 0 I 0 I 9 I 5 0 Valu. 197 . -. . . * I ; * I Oth~r (STORETI (116 IIi' Parameter . . FOOT NOTES .:1""; SlIúH..- of D.:Itð COdr'( D o R A '~tf1oll¡ó .1 p'I'\... 9<-'''"! oth..- IU"~ q"(ll. q"! .tV....(, '.port_d, EJ EJ - . I value '9;' G z ~ +<'5 ) ~Û;( (ã) 0 Lo ~c ~l ( FL.. ),::.., K.\\JE:e.. vJ ElL "" G ex 1/ K<2J iC J:.---I , \ I VI ..J S <?' 1/(. M -W DRILLING, Inc. C ::¡:. 7 T G "5 ¡;; /Ç. v / P· ~. Box 4-1224 · 1310C International Airport 'h."..ád (907) 274-4611 ANCHORAGE, ALASKA 99509 ,G--, C(7f/JAjJ t OC'&iL -h' ~ ~(' --- Ú L~ c;O~ ~A tßdÞ ~.~ / 4- z. DRilLING LOG Well Owner Citips Service Com~~ny Use of Wen cé\~t~lJ Location (address of: Township, Range, Section, if known; or distance main roan Ci t:v s('Y"vicc Cé\mpsite for East LE'wis ;(iver \"f:ll Size of casing 6 , C;2 Depth of Hole .L - . feet Cased to 151 feet Static water level Screen ( 9:?, ft. (åbo~e) (below) land surface. Finish of well (check one) open end ( ..) ; ); Perforated ( ) . Describe screen or perforatiol1 hC;l J', Well pumping test at k,1 ::.; gallons per (hour) (minute) for of drawdown from static level. hours witr. l:'\:~V ft. Date of completiol1 ì;· .:, ;..,- '7 r- WEll lOG Depth in feet from ground surface Give details of formations penetrated, size of material, color and hardness TO } TO " / r , ,,'_~ - TO ,.J r / TO .-¡ ~~5 1 ~..~; TO 14'; J.LrC TO 1<:; l~ ;' TO 1:-:1 TO TO TO TO TO TO TO TO - . ():,-aê.nlC S j; rO'},r:l C 1- a \. ~:i 1. tv Sé,n,; :". '_:rr\\JcJ_ ß1 ue Cl ?v H.&rdpi3..n f·íedium Gravel: waterbea.rina - 3 GPf\1 1dater Gravel: aood'saturation / r"tD '0 a: ::0 ..0- .þ...!o -.10 _0 tJt-D 00 tJ\(\) Of) .þ.{}3 ..ot1 &() Ui ~~~~. N\V''v A Certified Contractor Certificate No·s. 814 & 973 8- 2 -STATE ---"----- ----- - -- - --- A o. e, c. c, fe~ju.,áCa/ ¡re"v,'~¿.J. oJ' : ,Ct ^-"'é4 ¡j Cl ¿ e-,j~- e/<-~_/,/,'ú .JZ¿'~I ~ IL ¡;;; .tIe lJ-¡ ¿ueß / ¿~,'s Æuu- I!e./J. ..w.s.u-k,L>J.. ..fie. sÚ/;I'1:¡j~ cIo~ o."J .ofal7's;..s . !c/o . ¿e-.í¡,J!u^!C¡/& ¡:CoI7S ;~1 e/Y1." q n cl Cc L/~_--__Ge-I'7~~G. ... ___CQf<f_9._40J-_A -I¡'ð~- .of QftX)CGls ¡;~ 'J.:r,Q,r~ aua:!o,/;;{;/)j' Ù !f{eu;c>~s~ fJut/.,¿~le-jt~F:.clL~~-..Ír>ide.rGNds-nl .. . " . I 2.) 3 o! 2-\ £ Ie. I / ! ( ¡:e<(ì~ytJ ~ J i~ J 7 .¡:;.... m~-b2c..TO~ON"" flSiS .. ,() r 0.. ¡;; ~. .ð"u . c...Vo. . -. s- G.h1¡a.-e... ..- u.._"". ...QV.u .... ,j,) / / I, 1,1 I~. ;' / J Ie J/ ¡(/lre/v,=<. STn:;..-f'J'-OY Í) c.""m'.)u .~..4d/q,iøn,,-,,<:> TI¡f!.. . '. : j, ,..,. J.~-,.Q ~'" J .£ I. ,.- ),. f'rCJS~.. /¡ÚV~ 'NLO~.si / r~41G1't--J-'J .. .' (0//~ &-"4 .~~ u -.F~~<.Util-.n "Æe.Ú-;vex-",/.. ,Ve.fG'~/~.v of _ i<:,-'};':~s4c-uCi£C .uG,~0:kr. /s ,I:: ¡flY de";j ¡¡~AJ.~cI, ..~. u ...zf~ nu6f--J'i' a£ .7£<>-... ~{..Vole/ ç.Jc£~,;!Ju_-qd¡öc-e.'l"O z.fe- ...... )/}, -/ pad.:7 /'dC~-IkdJ).úJ~J.é!AJCcu'<4£J. .,~L!-c-L./\ f ¡;C4~.i-u:.c.l'CPI'r:.o;x../'7'Ò-. £ed._. /L1e<.$t:.-r-eJ d~¡¡'. - .' _.nn_"_ mu_·..···' .... .... ..... . t! ¿C-~1dY.<''''-J' . ......-. f II 0t=-e- /. /J-t. .l/'l~7) ...S;k.;'d7}~.!i~fr GQ~..¡ ~ e.- (jc;.St"-lJ' Aþ.slQ....n.A'k~{)I'¡./¡S.lD"'..L crCeotrylCP . '¡~y,J 0~fJ'Js,'~/~U~Je.7sJCiÜ,'c;Rr.¡1 5:.:;,;' . .. .f Ñe-J S t:J,.j / G. L.) . ..7 Y:5.In- f:esc...~SnO.. ..1e..s: -.. /)0 !J ~ c¡ . :~.:¡ ~d ~'2 ;)ro J~Ia/.~ ~rC~I's-G<>oI¡¡~/drAk.1k.. .". !r{. s-. Ceolo{J /Cq/ s;..rv~ f úJ.qll:Y - ,fe.£oc./'Gú. ~[/Jr~ ~efJ::-t J>S-//~j;:-.ru(l..~~'o/7 .... . . . .... ... ,11 ( // /) /J ~ ¡ ?{/,-. .>'_ L-Y_ I" j'J",./ .,__ _,. f J~ r~f- -"~_... "-.......... L~/£ -1/veJ () - ¡ . . Ai:-4A2r- ¿e:-ryo!;',J --- j j --- - - -- ,:t:/e.-/ /Jc;s¡'v-.JJ gj;si cv.- CI. s, CJfi/eq/5:..¿ye--y_·'u - - .;J ðeJ'7á ~Ud 'fU/~ L~l'j,~ J/f7¿'~¡~ J" 4 o. 0. C. c. .¡:;/~S"" C ) - ------ - - - - --- ,-. --,.- - ------- ----- - -- -- --- - -- ---- - - - - --- - - - -~---- - --- > -- --~'- -- ---~-- -". --- - ...- -_.-- ---" ------. ----.--,..--------. -- -- _._----~----- -- ------- --.".-------.- - ---- -- - -. -.. ~~- --- .---------- - - .------- --.-- - ~----- --------------"--- _. - - --.----,-...---.---.---- ____ ___ ____~_ ._ .·0"___ ~_ _.____~ ___ ___~___. _',' - __.~___ .__ __~. __ _ _. ________. .__ ,"___ _ ._ _"______ '_. ____~ ._ _______ .__ __~_______n ___._~________._____ ___.__ - - --- - .. - ---- - - -- -"---- ~----~_. -'." -- ---- - -- -,.-. --~ ---~----------, --.--.".-- - _._------_.~-~,- - - - --- -. - - - - ____ ______ F__ -- -", ---. -- -,- ----- ----. p- . - ---------~~-- - - - -- - ------------------ .---- ,~--- ---~-- ----~-------- ------- - ~---~- -- _..--. ---- -- ----- --- -.--- ---- - - - - -- - ------- ------~ --- ------ - --- ---.. - --. - --- ----- ~.._.~.. -------~----~------------------ ---- -- ------. ---------- -- -- -- - _.- .-. - --~ - -- ---- - - - -...5! I.": ~:::. I Q - --.L. ~ ~ () fORM NO 9-1904- A 1 ~ - ~ -} c¿ Cft D e \ -t Ak - J u, 04 SITE '-'" ' ~~ Recorded by_LvJ\Je\\ US DEPT. OF THE INTERIOR GEOLOGICAL SURVEY WATER RESOURCES DIVISION GROUND WATER SITE INVENTORY SITE SCHEDULE ~ English Metric Units Dole ¡ ) - <6 -7 , Check One GENERAL SITE DATA (01 Site Ident No I C; I I. J fi t'\ I 7! \ S 10.4/" 5 I \ i C\ I I 19 RG Number ~ Tr.nSKtion ~ Cð) D M V E add. dale". modify. verifiad Re:"ge~~~ Bu.~ IGS.. G ~ ~ 3i: Site-Type G C D H M T ~Relia~;13= i C (U) L M I~ collKtor. dr.in,sinkhol.. connector, multiple, pond,tunMI or...1I field checked, uncheck.d, location not, minimal well shaft accurata data 1_1Ll 1 I 1 1 --L L*J Dinrict~ State I 7= 1C)I.2G ~Ut:':n)~_~ PrOject No. r·s = I ~I ~ :6d i I Il) 10178 B Longitu~ ¡\ SO~,&¡511 ~ Lat· Long ¡ I ¡';:'\ r:l Accuracy L!~= l~F '-.!.1 M Ô sec. 5 se<:. 10 sec. M in ~ !\) ~ Latitude de; min dell min Local Numher Land Net Loc. :S*! merld 'S~ 81 o¡I¡4¡oÞ ~ 2: f /l/_~A lÛ-jE~ ~=-J.Q)) .J ~'*j ---.----- V·:: · .~~·l ·T 13= !S~EJ·41( S,lI} S I \ I~! . T ,Q--LLA}J __~,O.<i>,~ 1/4 1/4 1/4 section. township. range. .j.>~ Scale L~~-"-_ !-;: 1 '} " Location Map [14" 110']0 ,N II; K L JRj-:s¡ 1 ! _-L~.L.--L.-.l...- r .. ì 3 Ç)¡ ~-l -~ _l~J Altltud,' L 1 6 - ; - j Topo [19· D C H Sptting deprt"B,on < dunf-S. fldl. hilltop. Method of :- _ r A Meawrement ~. 7 -., u_ ~u alt1ffiE-ter, @ ~~ ~'~.EJ lelfel. r:~ -~-!;: AccuracyL'l~~ K 0---(;------ uu~-_-~--~--*_ Hydrologic !20_!\uO 0 C-~ 0-·... 2'*! n~~ - ~ __~~ _ _____~_ Unit (OWDC) L-----.::J ':'::L~u/~_~ Sin!., s.....amp, offshorf". pedlmf:nt, hillside. tE'rracf'_ undulating, valley, upland flat dra..... channcl 0"", of F HI\ I Þ - T , Constructlon!1 21" 13 :). ¡ '3 / ) .~ ;l1~~ COlHplt,tlon - mOfl1h day - Ule ,.---~ of : 2 3 = 1 A D Site '------- --:-~no-d~. drain, - ------- G H ø M R _ S T U 0 X z 1*1 mine, oil or, recharge, repress, test. unused, with· waste, destroyed gas drawal, --- ---- goo- selsrr.IC, heat, tMrrn.::1 obser'li at lon, US(· of I;\'dh'r [24 - r A B C ~-=~_._~~_--'- --~,~~ R bOltllllg (umrTIprclal. dt''''''21t'r, po....er. fife. domestic, Hrìga1ion_ medicinal, industrial. public. recreation. stock, supply U Y zFl T aIr cond., institution, unused, desai, other $ccondary WatpI Use . 1 ., 25' _d So f(1) . I . urce 0 29 = I D *; Depth Data ' , TNtldry UI"; 2 6 ~ r-r ~1 Depth of!; 7 )~~(:) D --------:~ Depth of 1-;~~~~-5·- of Watpr L . I I HolE , I, I ~ 1 I. I I I Well· ,,..t. . I ..; 1< Watpr Level 13~-:¡--=-------q L _ I 1 I j ¡51;. L _.1 J~ J Date Mealured ~ 3_ ~ =þ.1~ (.:2 ; '3 /] ) ,9 J 5: * J month day r.~T!1 SourceCD! 33 = ,1); * ¡ Method of ~"'aluremenl 1 I 34-.l.! ----------~-- --- -@ T V --._---_.~- -, * C G H M au1r,,, C.JllbrdtC'd e"S1lm2tOO. pres3.ure. calibrated. ge-ophysical. manomete-:- reported, S1e-e!. electric, calibrated. otne-:- ~Irllnt' ga:¡~ pressure ~ge logs. tape tapE electriC tapt> $1:" Slatlls ! 37 = r ~ z * <~ ----- -------- ------~- --- --~-------- ø G H R T V x - ------- -- dry flo.....llòg. nrorh". f 10'1"1 H)g n6ðrb'y. obS'tr'-ictlUn. pumpmg, recently, nearby. recently pumped pumpIng flowing nearby, forEign surface :,.·.·ate: recentl.,- subsur1ce effects pumped other d')~= ý-* Source 01 (11 f_3.'6_=_ b: *J Gcohydrologlr Data - _ _ Me~~~~itng~~~~_-"------~ Measuring POint Date Pump Used .2 5 = ¡~~~ 267= * month da.,· Q\',N[R IDENTlrlCATION 111 . I R = 158 ~ G® D M G add. delete. modify Name: Last ~C,I0 ,1 ,E IS, Date of . r;sg-¡¡-li"".. ? / -', "7/ , Q ï ..::-r;1 OwnenhlP ~v I.J .¿. I':> _ I \ I I ~L.:J month day y..r First f1s2=1s¡£ rLV:T Ie, f. Ic...,o~ r..···..-··..·EJ :::>::::>::.::-:.:::-:.::: * . ·I··~·· ~-, ·1··· ~:~i~;e! 1 6 3 = , ¡ *: OTHER SITE IDENTIFICATION NUMBERS (11 IR= 1890 C!:;J(Á) D M I~ Ident~,C),I, Ident~.o,\ cA, G ASSigner! 1 9 1 = i þ"k '1(\ .P ¡ * ¡ and. delE'te, modrfy r- --- ~ New Card Same R & T I~ AS~igner I 191 = II' KK Go >: SITE VISIT DATA (1) R=186G GAD M0 Dat.e of B VISit G 1ILiL¿Lj~ Nameof r~--·,~-- Person L-1~. ~_-'----L~-'---L_.L_-'--~ / / add. dfc-lt:tt modify month day ya.r FIELD WATER QUALITY MEASUREMENTS III R=1921*1 I T= I ADM 1*1 Date ~ G / / Geohydro· : 1 9 S ;¡ logic UnIt * add dtlett'. modlf.,· month New Drd Sa";:;" Ç#l 0 0 0 1 0 r;1 R th,u 195 _ ~ _ Temperature ~I I I I I I..:.J day year Degreel C /197 = ! I· 1 i * I lei~ ! * I ! * I Conductance 0 0 0 I 0 I 9 I 5 0 1197 = µ Mhos . Value 1197 = i Value 1197 = I i . I Other (STORET) 8 Parameter Other (STORETI r,;;¡jl Parameter ~ I~ I~ I. I FOOT NOTES: CD Sourcp of Data Codes. I S D l.___ Z I o R G A f "pOfllF)(] dll!I«, olhf"r ~lh-'1 other 1i...,t;S gt'L;()c.:'~I. other dg..nCy repCfled. .---- M - W DRILLING, Inc. '-' P. O. Box 4-1224 · 1310C International Airport Road (907) 274-4611 ANCHORAGE, ALASKA 99509 DRILLING LOG /(/ 8 o~,-., /.9 ß(J ,~ ~-, ~ 18 ,f) Ic.¡AJ 8"·\ c¡ F~) SO{-f VLJ 5' {.J Well Owner Ci ti ~ c. ~~,E :r\~icc C("JIi~P?,.':-IV Use of Well OJ 1 V,"':' ·.1 ;. .' t· Location (address of: Township, Range, Section, if known; or distance main roan ~)o. i. r ,\ i ~j'~<.'- j'ivcr \'('ll::i i-c- - roo, lUG:? /900 vJ Size of casing 6 Depth of Hole 3~ )(, feet Cased to 29~ feet Static water level Screen ( ..~ ::.~ ) ; ft. (above) Perforated ( >: Çbè1ÐW) land surface. Finish of well (check one) open end ( ) . ) ; Describe screen or perforatioI1.t11' ç.l c.-j-f-; ,.' F· -; ~ riP', - rr,';, '" -¡-,- ':>01', .-..;... Well pumping test at -:,.r, gallon/þ~~J·fhoh;),';.f(inihhiej cÍòf'·t~:~c":,? h6J~~: vi1fì,2-::1j~'~ ,·t ~ of drawdown from static level.·' (J't;: : (·1 ~ f 1 C' .' '.' :: 1. (i C:¡'J;''' ("-J I~<-+- ft. Date of completioI1 ;" _ ': f\'; é..r '/:-; ~---- J~ ¡- s -::i c ~_ i ~~j.~:' r ","- "- 1:) _ 1.:" j. :) fJ (-. WELL LOG Depth in feet from ground surface Give details of formations penetrated, size of material, color and hardness TO () :t" ;) 2"ri i c ~, -j TO l 1 r .", TO ~...J TO i " '7~ TO .i Ò ] 7f, TO ] 9? 1- 9~ TO ~! .:)(1 TO r) '-j L TO :-:;. ~)< , TO ,--- , ~ ' ... ~__¿:..nch; Gr" ë: ',r"".:. ~ v:::. : ~"~:.n[1·-/ C13\; }I(~~.2\.ti! if:! r~)1-- ~L]: " . ~ --¡ Cl é~,V Ouic}~~,and C12.vc\' GrEvFl ( 1 ( " :. ~--: i-"' ) . ;. J'" ';"- :~! -¡- &.-~ ~ ~~ ~ ~:-:- 'i ,".; \: ,"- . -, \. :: _ ~~ ~ c... 1'\:- -, ~ 1 ' . (' -::;·-:--;_'"n~·l t . , C· '"':- ~--~ _:-- -¡~-:.:--:- . (.....:.:..- 1 ~ .""-.. --. TO -:,(ì('~ TO TO TO TO ~~r:~ N\'V\VA CertiLed Contractor Certificate No'~ 814 & 973 . . r· ¡ ì ",..-;-.. .--- "1 "! t--, r- +- ~-_-:' ~,. c..; 1-- ;-. k'; r...~ 2 -STATE -4000 Lro~~~ ~ ID ~-J,J¿~ 1-~f~ i .....4100 j,()() 1 10 100 DDP-(L-ŒB)- 0 1 10 1DO IŒD--{s-DSH}- 100 1 10 .100 SIWJ.C1r-{8OL}- Dip below 4300' MD is consistently E'ly. TMD 8025 EXHIBIT 4.2 Unocal Oil & Gas Division ¡posed Injection Zones :ft side of depth track) UNOCALe ¡ted Intervals ght side of depth track) ALASKA DISTRICT Western Region LEWIS RIVER C..1 TO Dc 1 CORRELATION SECTION UPPER BELUGA FM. INTE RPRET A TlON R.B. STICKNEY 11-88 SHOWN CONTOURS FILE NO. EAT ¡¡Off UNOCRL76 L~ 977 5185 1. 9.1989 17~4& P. 1 c--" 2111T ·5 } . ¡Mot...c; ......)9 ) .)~~J.;\. I. uJ-- '- . -\-'i) Vt·yV ~y \ },I, 4.1 ¿p.¡r ~ Mr. IDnnie Srn1. th January 9, 1989 fage 1 January 9, 19a9 Mr. lDMie C. Smith o:>mmissioner Alaska nil and G~$ Col1Sèrv,;¡ti.on ~rrrniB$ion 3001 Poroupine Drive Anchorðge, Al~ska 99501 Da.u Nt. 8mi th. Lewis ßiver Well D-l ühaergrounð Injèot1on Application and 1quifer Examption Application In response to the questions ard comm@nts from Trustees for Alaska and the Alaska Center fo,· the .Envirt.1nment, Unocal would like to offt~r the fOllowing OO1TSner'lte; 1. Ul.x::cAL has nQt a¡:plied for a waste w~.ter disposal permit t.o the ACEC, because UAl&ska 5tatut~ 46.03.100 (d) statea a permi t frenl the Depar- trnen t of Env ironrnel1 t-al Conservation i3 not required for injection projecr.s pe~mitted under AS 31.05.030(h). 1be latter sbat~te gives ACr~ the ðutl10rity to administer the VIe Class II Program..." (letter fram Bill H. La~~reaux, Regional Supervisor, ADEC to candace lockwood, UNXAL, dated ,April 22, 19S5.) 2. A Coastal Project Questionnaice and Certific,;¡tiolî StateJœnt (QJe5tionnaira) not: required for an U1derground Injection Control (UIC) permi t. A Questiorui.aire is being prepaced and will be submitted to the DGC for the: facilitifts installation and operation. with regard to notifying the Matêlnuska-Suaitna .Boröugh foe a determination úf çor~sistenC'i' with the local coastal ma.nagement plan, tbey will be notified ðe apart of the p1'ocess of consIstency review completed by the DGC. ê ~ 3. As etðted in .2 above, the Coastal t>roject CUestionnaire and Certificati(.")n Statement is not required for a OIe permit since it only involves one per~lttin9 ðgency, the AOOCC. 4. The propJsed injection well, Lewis River Well 0-1, while outside. the Lewis River Unit ooundar:ies, is within the boundaries of the lease held by the Lewis River Unit..- 5. 'ltle reauested aauifer exstUotion refers to Lewis River !/r ON UNOC~L76 LA 971 5185 L 9.1989 17=49 P. 2 .~ '-.../ Mr. I£>nn ie 8m! th January 9t 1989 Pa ge 2 boundaries, however, it is within the boundaries of the loaac held by the Lewis Rivèr unit. 6. Beforo injection oonmanOO3, a ccnent bond log will be run and the casing integrity will be- tested in ~ocordance with 20 AAC 25.030(g)~ ñ1 addition, a step rate tast and teffil..;)erat.ure survey will be conducted to determine for.maLion fractu.re gradient and confirm injection zone isolation. 7.. '!he well is not dependent upon the use of dril1.lng mud f01- Zvl1$ seðling.. Should the casing integrity 00 found to be inadequate, cement squeezes will be perfoI"mc::..>d before injection begins. 8.. A maximum surface pl:essur.e of 1500 psi is clted as estio~t~ or appro~iro~te value. Prior to injection operations a step rate test will be performed to confirm t:he fOl~tions fracture gradient and establish the maximum injection pressure. 9. Q~ly non-hazardous waate5 as defined in ~JRA Subtitle C will be injected. Completion fluids õnd produced water will constitute the majot'ity of injection fluids. Sanple corrposi tions [(:>r these fluids was .tncluded in the permit applicacion. 10. S~çtion 300l(b) (2) (A) of the Solid Waste Disposal Act of 1980 (Pub. L. 96-.i80) Uexempts produced water I drilling fluids and other wastes associated witl} tl}e exploration, developn¡ent, and pt'oduclion activities" from classification as hazat'dous waste, and ther~fore, they are e1 igible {'ot· disf""sal in Class II wells I Rigwash i5 specifically listed as exenpt. 11. 'Iha only applicable t"êference in 40 ern 146 regarding compatibilìty of fluids ~coposed for injection with formation fluids found is· 40 CFR 146.22 (b) (1) which atates: All Class II injection wells shall be cased and cemented to prevent movement of fluids into or between underground sources of drinking water.....ln d(~teuninl.n9 and specifyin9 casing and ~rnentin9 t'equiL'ements, th<;! [0110wn9 factors sball be oonsidersd: A oun~r of [actors are listed and l46.22(b) (2) continues: In addition the Di,~ctor may consider information on: (j> Nature of formation fluid:!; (11; Lithology of injection and confjning zones; (it!) EX~ern&l pressure, internal pressure ar~ axial loadioCJJ ~ ~// (JNOC~L76 LA 977 5185 1. 9.1989 17149 P. 3 '-' Mr. Lonn ie 8m! th January 9, 1989 Page 3 12. '!he only applicable reference in 40 Cf'R 146 regarding compatibility of fluids proposed for injection with the teœiv ing formation found i$ also 40 CFR 146.22 (b) (1) II It is in r~'s best interests for fluids to be cOITfJatible in order to prevent solids from pn~cipi tating out of the fluid and plu99in9 the perforations. 13. UNOCAL1s calculation of the extent of radial invasion is based on a IWworst case II situation. The interval with the lowest porosi ty and thinnest sMd was used i¡¡ order to show the !uaxlmum pL'obable extent of radial invasion. 14. Tran8~rt of fluids will be in vacuuro truck from var.îou3 locations on the \'lest Side of Cook Inlet including l.ewia River I Pretty Creek, St.ump La~;e, and Ivan River. '!he íluid will be pumped from the truck to a 250 bbl surge tank which will pravide surge caf~lty LOt truck unloading wi~)out disrupting the water cleaning proce83e The fluid will then be pumped through a 250 bbl wash tank ð t a constant rat.e where the cOr!.densat:e, if any, will be separated and pumped to a storage tank. 'the condensate will be burned for fuel. ît1e solids will be settled out in the wash tank and peL""iodically removed. From U1e wash tank the liquid will be pumped to a 250 bbl clean ~¡ate[ tank, which will provide additional surge capacity as well as control operation of the injection pl1lJ1?S. A ill ter charge pump will p..urp the cleM wðer through a filter to remove any remaining suspended solids before the fluid is injecteã. ~~tering will occur during injection; and record keeping and ¡:eporting will be done according to the requit"a'nents set forth by the AOGOC. 15. a. A high pressUI"e :=hutdown switch on the injection pump will be used at the well head ðs a safety precaution. A check valve will be: installed on the tree which would prevent any backflow should the flCM 1 ine be damaged or leak. b. Subsurface sð.fet~i systems ðrS not needed alnce injection wells do not flow naturally. O,d Þccord1ng to 20 MC 25.252(d), mechanical inte<3rity must be œIftOnstrated acçotding to AAC 25.412 before ope~ðtiQn begins 4nd by monitoring the prc~oure in the casing-tubing annulus during actual injection. rrhe IOOni tored annulus pressure must be reported monthly to the AOOCC. r.NX:AL will cort1?ly with these requirements. ::J a r~~inn inrAðri~v ~~~~ina ~nd m~hani~al int~~;~v ~JM UMOC~L76 LR 977 5185 1. 9.1989 17=50 P. 4 "->-' // Mr. Lonn!é Snd t1t January 9, 1989 Pðge 4 / (. of t.hè well. UNæAL'a epecific workover plans for this well will be filed with thè Application for Sundry Approval as ~equired w1der 20 AAC 25.280. 16. Casing intçgrity testing and mechanical integrity testing will be used to insure physica.l integrity of the well. . The casing-tubing annulus pressure cannot subject the casing to a hoop strt!ss ÿ,.'hich exceeds 70 percent of the minimum yield strength of the casing due to limitations of the disposal equipment. Should a 200 psi change in pressure occu~ durù19 injection, it would would pose no potential hazard. 1 i. 'the water welJ. looated on the nO" pad is less than 300 ft...~t deep. ~1e shallowest proposed injection zOne in 2,5621 . 18. i'àter samples. from the original tests of Lewis Rivet" D-l, which exhibited extremely high s~linity values, are no longer accessible. ~le written reports of these tests are tha only data now available for reference.. '!his iníocn~tion is supplied, in its entirety, BS Exhibit 9 of tl1e Injection Application for Lewis River Unit, Well D-1, as submitted to tl1e AOGOC on 7 December 198$. In tbe absence of' reliable wateJ: analysis ððta, tJ'N<X'AL utilized the next most reliable data available which clearly shows that the shallow freshwater zone is isolated from the mud1 deeper zones that would be U5ed for injection. This involved induötry-standarà electric log analysis technique~ frClI1 which relative 61inity valuus oan be df~terrnineð as requit"ed for a Fr.eshwater Aquifer Exerrption Ot" an Injection Perfr\.it. 19. Any solids produced will be properly disposed of at an approved disposal sit..e and according to ADEC regulations 20. Documentation is on rile with the EPA authorizing the undersigned to execute any and all necessary perrni t applications on behalf of Union Oil Company of California, dba UNXAL. A copy of this docl1Jt\eotations is enclosed fot AOGCCls files. 21. "When a Slate UIe program is fully awroved by EPA Lo regulate all classes of injection the State a8sumes p(imary enforcement authority under Section 1422(b) (3) of SDWA.II 40 CFR 145.21(e) (See also BNA 41.2761 and BNA 71:6052.) ~erefore, EPA Form 4 is no longer required y 22,23 /!ùM UNOCRL76 LR 977 5185 If // / / I Mr. LoM 18 smi th January 9, 1989 Page 5 liholosure GÞG:FWS;ogs 00120 - 1. 9.1989 17:50 '~ Very truly yours, G. A. Graham District Operations Manager P. 5 s- ~r .~------ o SALINITY STUDY, COOK INLET BASIN, ALASKA By Don L. McGee GEOLOGIC REPORT 54 i; Ii ~u I ..--- ---- STATE OF ALASKA Jay S. Hammond, Governor Guy R. Martin, Commissioner, Dept. of Natural Resources Ross G. Schaff, State Geologist For sale by AIaakå Division of Geolodca! and Geophysical Surveys, P.O. Box 80007, College, 99708: 323 E. 4th Ave., Anchorage, 99501: P.O. Box 7438, Ketchikan, 99901: and Pouch M, Juneau, 99811 .. - ----- '-~ _c CONTENTS Page Abstract . . . . . . . I n trod uc t ion . ........... . . . . . . . . Interpretation techniques . . . . .......... 2 Definitions and water resistivities calculated from the SSP curves. 2 Definitions. . . . . . . . . . . . . . . . . Water resistivities calculated from the SSP curve. . . . . . . 2 3 ........ Vertical distribution of sal inities in the Cook Inlet basin Map presentation of the calculated water sal inities . . . . . 3 4 . . . . . . Interpretation restraints . . . . 4 Conclusions ....... . . . . . . .. . 5 5 5 6 Fresh water, plate 6 Sal ine water, plate 7 Summary . . . . . .... ............ . . . . References . ........ .... 6 ILLUSTRATIONS Plate Section 1 oca t ion map . . . . In pocket 2 Cross sect ion AA' In pac ke t 3 C ro s s section BS I . . . . In pocket 4 Cross sections CC I, D':D I , and EEl In pac ke t 5 Cross sections FF' and GGI In pocket 6 Contoured thickness from ground surface to ba se of the salt water--fresh water gradient . . . . . . In pocket 7 Contoured subsea depth to top of high sa1 in ity In pocket i i i 4;~ o ~ ...... 4¡tt: ~ rç\C <ç..C ~ Oc~ ~N .I , I , ) /' .-/" '"- '"-~._/' /~Jt>' ~ .~.f ~(I' ft' pOl'''' \ n C,Þ LiI% . 1> 1"0 . 1> ( < 8ril/o/ 8ay () GIIII of A/odø Þ AREA OF REPORT ~KODIAK . ~ l'ACIFIC J~ ~ 4 ( ~ ~ OCEAN '" lJE; Ft I NG ALEUTIAN Jl . 10 F q-" :.-<\·C¡ FIC ' . sß~ ~ ISl¡.,~D~ ~~ .~. <:¡¡:!1 p.... .0 ð () Loca t i on Map - ABSTRACT Exploratory boreholes drilled in the Cook Inlet basin for oil and gas yield data that can be appl ied to the study of subsurface waters. Tentative conclusions relating to oil and gas include the following: 1) the commercial dry gas is associated with intermediate sal inities and probably had a source in Tertiary sediments, 2) the oil migrated simultaneously with relatively salty water that probably originated from marine Mesozoic sediments underlying the Tertiary sediments either below or to the south of the presently producing oil fields, and 3) the depth to the high sal inity horizon (1,000+ grains/gallon NaCl) is increasingly shallow to the south and suggests that oil may be encountered at relatively shallow depths in the' south Cook Inlet. The sedimentary section containing fresh water is thickest along the edges of the Cook Inlet basin, which suggests rapid entry of water in the recharge areas near the mountains, and is thinnest or nonexistent under the waters of the Cook Inlet, where the sedimentary section has not been exposed to fresh water. The Homer-Anchor Point area is an example of an area with a relatively thin fresh-water section that 'may have salt-water invasion if the fresh water is extracted too rapidly. The Matanuska Valley and the west side of the Cook Inlet are examples of areas underlain by thick fresh-water intervals that should provide adequate water for community needs from deep-drilled wells. INTRODUCTION 'The availabil ity and quantity of fresh water is basic to the growth of any community. In particular, the subunits of the Cook Inlet basin, including the Kenai Peninsula, Matanuska Valley, Susitna basin, and the west side of the Cook Inlet are expected to grow at a rate exceeding the average growth rate for the entire state. Part of this report will examine, within the bounds of available data, the geographic areas of the Cook Inlet basin that have thick stratigraphic sections containing fresh water. The predominant data source .is the large number of exploratory and production wells drilled .for oil and gas, many of which penetrate nearly the entire Tertiary sequence of sedimentary rocks. Although plate 1 is not a val id map·for locating water wells, it nevertheless del ineates those areas where adequate fresh water may be available for community needs if reservoir rocks are present. Conversely, the map points out areas where brackish water is relatively near the groun~ surface and where it may ~e difficult to sustain large flow rates of fresh water. A second reason for examining the subsurface waters of the Cook Inlet basin is to relate the oil and gas accumulations with the sal inity of the waters in which they occur. This part of the report is related to questions that arise as to the source of the oil and gas in the Cook Inlet basin. There are several theories that have been proposed. Generally accepted is the theory that the lid ryl I gas, or natural gas containing very few liquid hydrocarbons, is from Kenai sediments rich in organic material. The source of the oil is generally more controversial but basically may be separated into the following theories: 1) oil migrated vertically from marine Mesozoic sediments known to underl ie the producing areas, 2) oil migrated from a marine source south of the present producing areas, 3) oil migrated from both of these, and 4) oil migrated from Tertiary sediments; this is the least 1 ikely -1- -- source, and is based on the separation of the water sal inities associated with the dry gas and oil accumulations. The conclusions listed in this report are presented as tentative ideas, not concrete conclusions. INTERPRETATION TECHNIQUES Formationwater resistivity, directly related to the quantity of dissolved salts in the formation water, may be determined by several methods, depending on the basic information available. In an area where considerable exploration and development drill ing has occurred, water resistivities have often been compiled_ from analyses of formation waters collected from different fields and different producing horizons. Values from this source are sometimes 1 isted as chemical analyses and may be converted to resistivities or NaCl-equiva1ent concentrations. In many cases, however, water produced from initial production and exploratory tests is diluted with filtrate (water) from the drill ing fluid and the values are incorrect. If there are no available data or if the data are restricted, accurate values of water resistivity can often be calculated from spontaneous potential curves on electric logs. Water resistivity values are then converted to sa1 inities and reported in grains per gallon NaCl. DEFINITIONS AND WATER RESISTIVITIES CALCULATED FROM THE SSP CURVES Most of the water resistivities were calculated using the format and charts of Schlumberger (1973). To understand the basic calculations, a number of definitions are listed below. Definitions a. SSP (static spontaneous potential) - A curve on an electric log that shows the spontaneous potentials at different depths of the borehole. It represents small electromotive forces caused by either infiltration (by the mud filtrate) of the reservoir rocks ·or possibly by an electrochemical reaction between mud and reservoir fluid (AGI Glossary of Geology). b. Rmf (resistivity of the mud filtrate) - The resistivity of the fluid portion of the mud system, which rßpresents a mixture of the make-up water (water derived from a surface or shallow subsurface source and mixed with the required sol ids and chemicals to form a mud system), of ions from chemicals added to the mud system, and of contaminants from the drilled formation. c. Rw (resistivity of the formation water) - A measure of the conductivity of the water present in subsurface rocks: the lower the resistivity or the higher the conductivity, the more ions present and the saltier the water. The end result of the calculations described in this report is a specific resistivity of water from one subsurface Interval at a known temperature. This value may be converted to grains per gallon NaCl. A general assumption is that the deeper waters can be treated as predominantly NaCl solutions. In fresh water, salts of calcium and magnesium become important, bicarbonate water is common, and a direct Rw approach becomes difficult. d. Temperature - Determined by establ ishing a temperature gradient based on the maximum temperature measured during the logging run and extrapolating it to the depth where the Rw calculations are being made. -2- .,- e. Connate Water - Water entrapped in the interstices of a sedimentary rock at the time of its deposition (AGI Glossary of Geology). By this definition, much of the formation water is not connate water, because migration of fluids within a basin and subsequent intermixing by fresh surface water changes the primary character of the water. In this report, the term "connate water" is not used and would be represented only in impermeable rocks that have prevented migration of the original fluids. Water Resistivities Calculated from the SSP Curve Th b . f I - -K (RmfÓ~, L~· h . ld h I· d f h SSP e aSlc ormu a, SSP = (RW)'~IIIC Yle s t e amp Itu e 0 t e , was used. The water resistivity, Rw, can be calculated from this formula since K (related to formation temperature) and Rmf (resistivity of the mud filtrate) are known and the SSP can be read directly from the log. The procedure is as follows: l. Pick the sand with the least amount of shale (cleanest sand) in or near the interval of interest. 2. Calculate the temperature at this depth using the maximum temperature for the logging run (recorded on the log heading) and extrapolating uphole temperatures to the required depth (Schlumberger chart A-2, 1 973) . 3. Determine the resistivity of the mud filtrate at the calculated temperature. This i? done by obtaining the Rmf value measured at the surface usually at a lower temperature (log heading) and determining the resistivity for the formation temperature with Schlumberger chart A-6. 4. Determine the value of SSP from the log curve by establ ishing a base- l ine and measuring the excursion of the curve to the left of the base- line. '5. Solve the SSP equation for Rmf/Rw by using Schlumberger chart A-IO. 6. Determine the value of Rw by using the value of Rmf and con~erting Rw at a known temperature to grains per gallon NaCl with Schlumberger chart A-6. VERTICAL DISTRIBUTION OF SALINITIES IN THE COOK INLET BASIN Water sal inities in the Cook Inlet basin may be essentially grouped into the following four concentrations, each with a particular sal inity range. .~ ., 1. Fresh Water - "Fresh waterll as used in this report is water that is usable for community needs. Nearly all of Alaska1s fresh water contains varying amounts of salts other than NaCl. In many of the wells in the Cook Inlet basin, a salt water--fresh water gradient is present; the base of this interval has been chosen as the base of the fresh-water interval. These waters are I imited to the upper part of the section and largely represent the water that percolates into the reservoir rocks from rain, stream, and snow accumulations. As might be expected, the depths to the base of -3- '-' the salt water--fresh water gradient are deep along the marginal edges of the basin, where porous and permeable rocks are exposed to streams and other sources of fresh water, and are shallow or nonexistent under the waters of the Cook Inlet, where they have not been exposed to fresh water systems. 2. 51 ightly Salty to Moderately Salty Water - The sa1 inities for these waters. range from sl ight1y saltier than fresh water to less than 200 grains per gallon NaC1. This is the zone in which intermixing of fresh and salt water would be expected. 3. Moderately Salty Formation Waters - These waters have a sal inity in an intermediate range between brackish and salty water, from 200 to 1,000 grains per gallon NaCl. They represent water of about the same sal inity range as the water present when the original sediments were deposited. They are not considered connate waters because of the probabil ity of migration in the more permeable sediments. 4. Very Salty Formation Waters - The term livery salty·' is used here in a relative sense---none of the very salty formation waters in the Cook Inlet approach the high sal inities often measured in other þasins. These waters have sal inities in excess of 1,000 grains per gallon. Because of their non- marine environment (probably deposited in brackish water) they may represent either vertical migration of salty waters into stratigraphically higher reservoirs from an older source or migration of salt water and oil from a source south of the present productive areas. Because nearly all the oil accumulations in the Cook Inlet are associated with formation waters with sal inities in this range, a correlation may exist between the 1 iquid hydro- carbons and the relatively salty formation waters. ;i ~ - ~ -. .-. ¿; .: MAP PRESENTATION OF THE CALCULATED WATER SALINITIES ::! Logs from selected boreholes drilled for hydrocarbons within the limits of the-Cook Inlet basin were analyzed and values of water resistivities calculated. These values were then transferred to cross sections (pl. 1-5) and maps were constructed. Plate 6 is a thickness map contoured from the base of the fresh water--salt water gradient and represents the interval from the ground surface to the approximate top of salt water. Plate 7 is contoured on the subsea depth of the l,OOO-plus NaCl grains-per-gallon water; it-represents a surface below whiçh the waters are all relatively salty and is also the top of the section in which nearly all the 1 iquid hydrocarbons (oil) occur in the Cook Inlet. t; .~ .~ -. -" INTERPRETATION RESTRAINTS ~ " ';""1 There are several problems inherent in determining the water resistivity from the SSP curve. In the shallow intervals, salts other than NaCl are commonly present. In the deeper intervals, analyses of formation waters obtained from tests in the Cook Inlet demonstrate that nearly all the salt present is NaC1 and that other contributors to conductivity may be ignored. SSP basel ine shifts, or the tendency of the curve to drift because of mechanical or electrical functions (common for logs run in the Cook Inlet), sometime makes it difficult to measure the SSP departure. Sometimes an electrokinetic potential affects the SSP. How- ever, this component of SSP can generally be considered negl igible in the Cook Inlet because the sands have adequate permeabil ities, the deeper waters are -4- 1 '" ~ ~~ ,~ ~ ". ,;::.i ;'.J .~ ¿ ;.-, ~ . . M ~ ï· ~~ '- ',,-, salty and the drill ing fluids are generally in a normal pH range. Probably the greatest introduced error is in determining the depth where sa I inity changes occur. There are thick intervals of silt, clay, and clayey sands that do not contain sands that are clay-free enough to make salinity determinations. Calculations below and above these intervals often show that a sa 1 inity change has occurred, but the depth at which the change occurred is not known. CONCLUSIONS Fresh Water, Plate 6 1. Plate 6 indicates geographic areas where thick intervals of fresh water occur. Because adequate fresh-water reservoirs must be present, the map cannot be used to directly determine the quantity of extractable water. However, it can del ineate areas where problems may occur if fresh water is extracted too rapidly. The Homer area, for example, is underlain by brackish water at a relatively shallow depth, and the use of fresh water at high rates may cause salt water to enter the wells. Area~ such as Anchorage apparently have an adequate interval of fresh water, but thic~ portions of the section do not contain reservoir rocks. The Matanuska Valley, on the other hand, has a combination of adequate reservoir rocks and a thick fresh-water section, which should present a favorable water ,source. 2. The thickening of fresh-water intervals near the basin edges is related to proximity to recharge areas and to possible preservation of fresh water originally present during the deposition of the sediments. 3. La rge a rea s on the wes t side of the Kena i' Pen i nsu 1 a have th i ck fresh-wa ter intervals and should have adequate water from drilled wells. 4. Thick fresh-water intervals are present on the west side of the Cook Inlet and future growth needs could be easily .supported---particularly industries requiring large amounts of fresh water. The steep gradient of the base of the fresh water to the west---from none under the waters of the Cook Inlet to thousands of feet in the Beluga area--- may be partly related to block faulting but may also represent large areas of surface-water recharge. 5. Sal ine Water~ Plate 7 1 . All the commercial oil accumulations in the Cook Inlet are associated with relatively salty water (1 ,OOO-plus grains per gallon). 2. All the commercial dry-gas accumulations in the Cook Inlet are associated with less sal ine water (200 to 1,000 grains per gallon). Waters in this sal inity range are bel ieved similar to those associated with the sediments during deposition. 3. The arcuate salt-water ridge containing the known commercial oil fields in the Cook Inlet may be related to vertical migration of water from older marine sediments. The configuration of this ridge suggests that structure is a modifying but not a controll ing physical element for the top of the -5- ""..- .... - v-= -- -- high-saJ inity surface and that a relationship exists between vertical salt-water migration (migration from marine Mesozoic rocks) and the configuration of this surface. 4. A sha1 tow high-salinity belt on the west side of the Cook Inlet extends from the mouth of the Susitna River apparently into the south Cook Inlet. The top of this surface rises rapidly near the south end of the Kenai Peninsula (south of the Pennzoil, Starichkof State 1 and the Occidental, South Diamond GuJch boreholes). A1though control is 1acking, the configuration suggests that the depth to high-salinity waters in the south Cook InJet may be sha11ow. The presence of oil shows in the Standard Oil of Cal ifornia North Fork Unit 11-4 and the Pennzoil, Starichkof State 1, both associated with salty waters, again suggests a relationship between the oil and salt water and the possibil ¡ty of a similar genetic source. 5. Plate 7 also suggests that oil would be confined to deep horizons in the eastern part of the Kenai Peninsula. Summary This report suggests a genetic relationship between oil and associated salt water. The sourc~ of the J iquid hydrocarbons for the known productive fields is probably from underJying marine Mesozoic sediments. This does not, however, preclude the possibil ity of migration of oil and sal ine water along the west side of the Cook Inlet from a marine source south of the oiJ-productive areas. If the salt water is acting as a transportation medium for the liquid hydrocarbons, there may be shallow Tertiary oil accumulations in the south Cook InJet (pl. 7). If, as indicated in this report, the gas is associated with Jess saline waters and probably derived from Tertiary sediments, the section containing dry gas may be relatively thin in the south Cook Inlet. REFERENCES American Geological Institute, 1973, Glossary of geology (Gray, Margaret, McAfee, Robert, Jr., and Wolf, C. L., eds.): Washington, D.C., p. 150, 683. Schlumberger Well Surveying Corporation, 1973, Log interpretation charts: Houston, T exa 5 . .~ -6- .... f" +.+*......+*..**~*** · * ~ * ~..*.*.*....**..*.*. * * · ~ C rHI lJ M l; t 1'< ~ ¿ t( . · . .+++.*.~..+.**~**..* GC1 D1R~Cl1u~AL Sukv~t c u ~ T l)r1 r H L 1 ~&. 1.-. (~ to lit< i ~ en :;:::0 Qo 1"11 m >ø -0 n g.m I\.) m ~C') ..t-- ~o ï < co ~ ( C") in 0 0 3 3 ëñ· tn õ· :::J A't'L¡~hl'fTC 1"\ ((Hi:'" Ir~t 1.) CU" 'ì./~ - ¡ t<UPARUF ~; \1 k l' ri S L LH' t-;, i\ L A ~ r, A ~ II H Ii 1:. 1. lJ A ! t: J - J lj.~ .. d 4 ",¡~<"';lr~r..Ek: ¡VlC JJHl.Uc. '.q;. 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'\0.00 Ä D.00 2-,,,,,0.00 ;l800.0Ú 2900,Ov JOVO.OÜ 31uO,(H) 3200,00 3300,Ol,) J4ÙO,OO J5úû.O(J 3000,00 J100.0~¡ 3800.00 3900.00 1 R l; J: ;.:, III ~ - S 1:'1'1 C f I ~ ¡: ;» 1:: '" 1:; A S LJ k~: iJ V ~ K l' j C A L \,J t.. k 11 ( 1\ ~ 1J t:.; V I AT 1 v I~ I, Z 1 ¡'Ill ... ~1 ü~:P1'H lJr~" 'f11 ¡lEt) l'11 DI::G MII~ l F(., '; I ,,~ l¡JTt-·¡..,.I-\¡(,t\Tt. \'jILld-.., rr,:I~ r.'Jt'.:r. lIlt; ~,:;~'r uf Mï:.:A~;U¡.H:u lJEP'rH iNGI~[~R: MC HKIDE lJ A l' r.. u ... S U k ~ ~; .: j .. J U N - tI 4 ( ~ I. ~ Y B l.J S Hi f-. GEL E V A T l UN: C :.; I ' t ' L' I ;~ I 1\1, ~ t, 1\ {to,: 1 3 - J u (, ... H 't A'lL ANT 1 C !~ i C ( t! . .L" I.. I· Cu. 2A-') r<. lJ t' A t< lJ ¡\ i't 0.... 'f Ii .:; I \ I P 1:" J\ L, ¡.;.,:\ ,~ ~ LU 1'. r' tll' A 'J 1 t; ¡', U~~~: lj-0ul.-t14 PAGE ~ ATLANTIC RICIH'll'.LD ru. D~1't. üf' su~~~t: 3...JUN..84 2A-2 r\t;l,LY HuSltll~G F.LEV A1' iUN: 130.00 FT KUPAkUK. ,'4 0 R T H :) L u P 1'''; , i\ L tL.> I' A r.: N G } jl.¡ E E: R : MC Bk IlH: 11\ .1 ~. K ~I I. .II, 1-\ . r t I . V ,.. j, \J r..> F II 11' t V ~~ ('j 1 (It\ ~i'...¡'. r ut-" M~A.JUtH<,J i)E~Th 1'R LJ 1:< S t J Ii - ~)(.; f\ C t ' '-' r ~, t'~ V r. h' 1 teA L Ùt ¡(, Lt:..", r. f C '} A I~ ~ U L A I-< CO U R l) I N AtE.: 5 HUt{ I Z . DE PAR T U It t:; Mt:ASUt<Eû ~~~k"'Ir.AL V~~1I(AL U~~lATJ~~ AZiMufh ~ ~ L T 1 (J ¡~ ::>t.1J1:.t{11~ ~U~Th/SuUfh ~A~t/Wt:SI VIST, AZIMUTH DE;PTH r)l:':vrt1 Dt:.:l'f'1 út'~G re11 r. l' F (; I': 1. I" rr' ~,'I Pt~()/lUO ~~~r YEff F~lT DEG MIN '! () U 0 , 0 ,I .i < ') J . 1 .J J / ':J .i . 1 ,~ 35 14 ~ (~ it:. ~ 3bY.5b j . 4 ( IHq.~j N 320.47 ~: jb9,ijO III" 4t: 4100,Oll ~UOj..l~ jH/3.1H 37 34 1" ~'::t 1 ':> r, 4:lY,,4ti l".l~ ;¿1~,70 ~ 3J1.02 ~ 429.11 N 51 t:: 42lJO,O\.1 40dj~1~ j~~~3.1J 35 54 t ~) '.I d f 4 ú 'I . 4 :i l,'71 24b.2Y t; 4~3,24 E 489,68 N 4d r.: 4JOO.()\.J 41bS.lJlJ ,,*l)j~.\JU 34 2~ I, ~() L h ~_ ~4b.~j i.\Jb ¿ I ~ . '::I I I~ ""~,4t1 ~ ~47.~7 N ~' 42 t. ,. ,~ 0 (; , C u .. 2 1 'J . t. 1 't 1 1 -, . 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L b 'it)¿4.1ta ~~ l~ [\ ~4 ;¿~ ~; 'J;¿4.:¿4 1 , l ~ ~~ø,l!> ~ '1t$",ti2 ~ ~2~.~4 N ~t1 I i:: ~100.0Ú 4,b11.51 -i711.~ï 2H 3h , !14 2~ ~ l F;' . ., ¿ 0,78 ~lb,Jl N b24,J~ ~; 912.72 N 57 50 ~ I'. ~20ù, Ol) 49;¿'.:I.'1~ 4 ./ ".J 9 , Y ~ 2b S~ f\: 5 '! ;¿ t> t,: 1019.3;¿ 1,!>1 ~43,4~ N ijb¿,Jb ~ 101~.J3 N 57 40 t; ~300,O~) "Ol';J,o~ qu8':J.b~ 2S 46 "" ~3 51 F 1063.49 ¿"O1 5b9.4~ ~ ~~b..lt t: 10b3.51 fo4 57 37 ~ 5400,O\) 511U.3.j 4YbO"jj J.4 I!> r,l ~j 1 I ~, 110~.~2 'i. ~~ !>Y4.50 N ~j¿.12 ~ li05.~7 N ~7 28 a:.; ~~{)(I.Ov 5202.10 ~')o77.10 '2.2, ~5 ì,. ~J 11 t 114~.Oti 0,30 bld.Jb N 90J.Ùb t: 1 4!:i,lb tit 57 19 ~ ~bOO,OÚ 5;¿Y4.~H ~1t.,;4.5o 21 ~~ .. ~ 4 ~ () E; llti3.04 l.:¿l 04u.l/ N ~~4,b2 E 118J.l~ N ~1 1~ t:; ~1uO,no 5 3 ~:r/ . 0 ~ ::>LS7.t':l )1 1 1 ('- 50 d f 1219.4~ ~I. 39 bt-l.3~ N 1024,07 l 1219,58 N 5'1 9 t; 580ú.o.O ~4~l.l~, ~3~l.1" "J.V 37 1\ ':> ¡ 11 f:~ 1:¿~4.Y¿ 1,10 bt10,ij;l N lU~4.jb ~ 1~5~.Ob t'4 b7 tt ~ 5900.()ü 5~7t>.21 :>4,,*1).21 1 t1 ~ ~~ , ~b 2'l E )¿dH.C)7 1.26 bYb,'jt> N 10~Jwl~ t: 1289.11 N 57 10 E 6000.0v ':H...t, ~ . ~ I~ ~)~j9.':I~f: J ¡) 20 I" ~'::4 3') F l]/,O.99 \) II I:} 7 715.·H) N lllO.bl t: 1 j 2 1 , 11 N !>7 12 t; bl00.00 !)"b~.4:t ~)bJ~.4;¿ \ú 30 I· bO ': t, 13!>O.6ti 1.20 7jU,Jb N 11Jb,31 t; 1350.79 ~ 57 10 ~ 6200,00 ">bbl.Î) ~ '7 j t . 7 1 14 ~3 r hJ I. 1 f' 1317.62 1.30 743.5U ~ 11~9,d7 ~ 1377.71 N 57 :¿O E ó300,OO ,)~~Û.:">I) ~1')2~.~O 14 19 ¡ , l) ¿ " I E 14U2,7ú V,b) 7~5.2;¿ N 1~~2,12 ~ 1402,71 N ~7 2~ i:: 64uo.00 6()~S,4:i ~Y:¿!).4;¿ 14 19 ,\" b3 1. t, 1427.7.3 O.~l 7 b b , 4 " N 1 04,02 ~ 1427,28 ~ 57 31 E ~,,, ., 0 0 V bl!:>¿,<j~ oOi2,,/llj J.~ 4'.> 1\ b3 1 t.. 14~J.24 ú.vO ï "7,~U N 1~2~.~O ~ 14~1.27 N 57 Jo E , - O,OJ 624'),0) ullY.?l 13 ~? h f~ j 1 f 14'74.9.1. 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" ~~ '1"1: f\ I I (;~: 1-1. P 1\ 1 C A 'f'1.1A I.. TIC k 1 C H"'l t. L. t) L U . 2A-2 t\UpAKlil\ NlH<'T't\ ::,LUfJr;, I"L/I.bhA CU¡';Fu'1 ~1J.1l.J ~ uA..It<: 1 ~-0UL.-t1't Ø3/21:;V1j~ l~: ø~ u:¿"t:> ~¿¡L ¿¡.L"i.L ", ct' J\ - 1tC\J J VJ.., l ~ Lf6I '(,/'(,/G "eø ')".,~ . ft IJI, t=) ~( PRr1et.~ u.s. ÈNVIRONMENTAL PROTECTION AGb-q"CY REGION 10 1200 SIXTH AveNue SEATTLE, WASHINGTON 98101 REPLY TO ATTN OF; WD..132 RECEIVED cm~ COêJ1M . u_~ Cn[;J~\!~ I' I -'n.d ~ ;~);[~-/ ~ I ~\'~~'.J I I E~·,I:::' . ".~ c' ¡;;:'-;'¡"~I I! J '·.A f i:-; 0 I r"\:t""<'"t .-..~------ .... 'ì· ,-' .., ,...., I I '-~ ~ "",---" b;. v I....... GEOL ASSTI GECL ÞiSS! i ~'r A T '~~r-r-'-l ¡ i~ì;AT ~,t(~;.~!- r'7fLE----¡-~ --'--..-.. -=,,--><=-~- AfAR Z B 1U9 MAR 2 8 19RO c. v. Chatterton 1 .. . . Alaska 011 & Gas Conservation Comm1ssNftskaplJIc GasCons.CømMJr 3001 Porcupi ne Dr1 ve 'J~ ~or.aø,~·::r~"",,-·'=_L . Anchorage. Alaska 99501 .. Re: Unocal Corporation Aquffer Exemption Request December 1, 1988, for Lewis River Field (Well D-1) Dear Mr. Chatterton: We have rece1ved and reviewed the Comm1ss1onls February 16, 1989, letter recommending the approval of an exempt10n for the aqu1fers deeper thAn 2,300 feet for ð one-quarter mile rad1us around Well D-1 at the Lewis River Field for Class 11 1nject1on well activities on1y. Under,the Environmenta1 Protection Agency's (EPA) gu1dance addressing aquifer exemptions this would be a minor aquifer exemption because it 1$ re1ated to a permit action for ,8 Clats II inject10n well. Due to the fact that this aquifer has totol disso1ved so11ds (rOS) concentrations in excess of 3,000 milligrams per l1ter; the propo$ed exemption is not treated as a revision to the state program. However. 1t must receive approval from EPA. It would become final without EPA approval if EPA failed to disapprove 1twîth1n 45 days of the date of your letter (See 40 CFR S144.7(b)(3)(1i}). A$ you recal1t when EPA de1egated the administration of the Class 1·1 inject10n well program to the Comm1ss1onþ we incorporated the relevant A1aska regulations by reference (See 40 CFR §147.100). Consequently. when we cons1def an exemptfon request, our obligation is to confirm that the request would comply w1th the Alaska regulations for exemptions. If the exemption request complies with these regulations~ then EPA can be assured that, with the exemption. the Alaska Class II injection well program will continue to protect pub11c health and the env1ronment. Based on our rev1ew Of the adm1n1strative record and the f;nd1ngs and infonnation presented in the Commission·s February 16th letter" we conclude that the exemption request would meet the requirements of 'the Alaska regulat1ons. Therefore, with this letter we accept the Commission's recommendation and convey [PAis approval of the exemption. Add1t1onal1y, EPA, 11ke other federal agencies, is required to ensure that its actions are consistent with federally approved state coastal zone management programs. Based on our rev1ew of the records and our discussions with representatives of Alaskals cOðstal zone management agency. the Division of Governmentol Coordination in the Governor's Office. we ha~e concluded that our action approving this aquifer exemption is consistent with A1aska*s Coasta1 Zone Management program~ ~ ~ 03/28/89 14:03 , U20ö 44Z 4141 t.tlA 1(t.(,,¡IUN 1., ~ \7\7~ 'r ~.. ..,>M ,...-..;. '- '-' "" 2 - We art awere of numerous public comments on the proposed aquifer exempt10n and the need to reso1ve public misunderstanding about the exemption proceS$. We agree with your recommendations on how we shou1d address these concerns and will work with you to amend the MOA to better c10rify the aquifer exemption ·process. S1 ncerely 11 r~.1\M.tJß'4~1 Robert S. 8urd Direçtor, Water Division cc: Allison Smith, Dfv1S1on of Governmentol Coordination Randall Weiner, Trustees for Alaska Krfst1ne A. Benson. Ala5kð Center, for the Environment G.A. Graham. Unoca1 Corporation , ! ... " ~ .I $fl3 ¡f~ ·Iw~ ~~ ~ oJ- /('0 ----~ "- ð ?f>--¡ /.5) . '.'.J ø- I.:¿ j. :/L- --,» fS (/"( .:.. ·7 q _ .-, () , ( (' ~ [ (] ~ JJ.; .lJð " '~, ( ;:~.. 7/ ~ ".,' (' _ b f .. " I . b I .....J I / .- ,- .~..~."- f . ;;w ,9 ~$ ~ .. 6/ ~6Y; I ." . /. ~) ,':' I ¿i ¿J . . . f /1. /,/A / '!" u .. , / . - .. .. . / ,),. I . ,,',. / , , ~. /,. ,,!.. .~' .. o,s/ .. ò ) 2_.. /.J:, "I ; ..'=' f úr k 'C.. -It...,,/, ~ ~ s ftf I 2 s: (~1 s¡; ¡::- r7 S'Cj CJ Yo/ C) -, J ., fL. C (" J . ç ,/ c:'- Lí / .'> IS'> ç-' ~ ) ) '-- . c fi¡ C:' cJ c.." '(, ',( ' l ') ,~-. '1- -, ., , ".!'- ) L .... J (:; OJ ~ ." I .') l c··· . I J r - /'" l / .. ",.' ) :)-- / . I ',-, __ } I. _ ,\ ....... , : .,:", I.. .., . J " ,. l. ! .' ' ! : / C) ;' ,-. c- / J I (~ .. () {-::- ¡,~. fy ~f /-.Mj 5 LJ' J ,I / .. . J /' ,..,; . .. _. . L L·I ( .'.' ' " .., _, " ;:. (~ I ,~' c ¡oJ _j." ¡ 1)/1,,: ,~-(;_~... b b to!'. ({ {¡ ,I, I.{ /f ) r~ ( 1 t\ ¡; / . :v J /' {, ,.<2...{ /. ú (~ l ::. , '~.~., 7 (J"F ,¿ r: /. Ó (. ...} / . ..-. , . ,...' ~7(f'" Fr¡-:: ,-.,' - .' '1 ".' II t :.-) r c) - (, ":. - i L} i :. J "\ .L 1 , /' : .~. f(; !\Y!ff 55: f~//M~ 11;t1 r~ 'j ( /,;'( ) ':r,r,'\ ) ~,~.,r· ~ '} ..' ) . .JI (. (\ , , ,. ï /"1 , / f ') ,()(} () ( / I / ': () . 1 .) (),) j 1(' c, , ,.. (' ~'.. J c..·· .) I f.... It I I LE-yvIS RIVER ··-JNIT INDEX· MAP f 1" =2000' 27 28 29 34 T 15N --- R9W T14N-R9W 3 10 1/4 MILE RADIUS ... I W( -$a LEWIS ~.! D-l \_ . TD 8025 I r -, ~ /-l I I ~ . 1 r- . . ,s .& LEWIS R. ell I~ TD 6570' I IW I> l1:: !(f) r - J @ I .p. LEWIS R. #1 ! i TD 9480' L - I ---12 L -~-'LEWIS R. 13-2 I TD 11,625' I 36 1 LEWIS R. B-1 TD 10,319· I i I EXHIBIT # 1 LOCATION MAP o - Table 1 Depth Dens. Equivalent MD SS BGL Tfm Paras. Rt Rwa Salinity (ft) (ft) (ft) (Deg F) (%) (ohm-m) (ohm-m) (ppm NaCl) 2576 2451 2551 65.7 25 12 0.98 6,900 2590 2465 2565 65.9 24 13 0.98 6,800 2853 2728 2828 69.2 20 16 0.81 7,700 2878 2753 2853 69.5 18 14 0.57 11,500 2892 2767 2867 69.6 19 17 0.77 8,000 2955 2830 2930 70.4 22 20 1~24 5,000 3024 2899 2999 71.3 16 25 0~78 7,900 3038 2913 3013 . 71.5 14 25 0.59 10,000 3482 3356 3456 77.0 17 20 0.71 8,000 3717 3591 3691 80.0 15 21 0.57 9,500 3740 3614 3714 80.3 17 18 0.64 8,200 3758 3632 3732 80.5 19 17 0.77 7,100 3885 3759 3859 82.0 15 25 0.68 7,800 3912 3786 3886 82.4 16 28 0.88 6,000 MD Measured Depth SS Subsea Depth BGL Below Ground Level Tfm Formation Temperature Rt True Resistivity Rwa Apparent Formation Fluid Salinity -- EXHIBIT 4.3 -' Methodology for Calculating Salinity from LOQ Data Resistivity, read from the deep induction curve (Rild), is assumed to be the best aoproximation of true resistivity (Rt) of virgin formation beyond the zone that was invaded by drilling fluids at the time of logging. Porosity (Ø) wi thin the ZCXìe of interest can be read directly from the density porosity curve (Øo) on the neutron-density log. Knowing these two parameters, it is possible to calculate the apparent resistivity of the fluid within the formation (Rwa) with the following relationships: Rwa = Rt/F, where F = O.62/¢2.15 (Humble formula) *The parameter "F" is the "formation resistivity factor" which eliminates the effect of the rock itself from the resistivity measurement so that the resulting value (Rwa) represents only the contained fluid. Rwa values, when corrected to formation temperature (Tfm) can be used to determine approximate salinity with a standard nomograph (Exhibit 4.4, Dresser Atlas, 1975). A straight line through any value for Rwa (on the right stem) and the corresponding formation temperature (on the left stem) will intersect the equivalent salinity (on the middle stem). Formation temperature is determined as shown below: Estimated Mean Surface Temp (MST): 35 deg F (for Cook Inlet area) Maximum Recorded Temp (Tmax) from FOC: 135 deg F ® 8025' TMD (-7889), i.e., 7989' BGL where BGL = Below Ground Level Thermal Gradient (TG): TG = (Tmax - MST)/(Depth BGL/lOO) = (135 deg F - 35 deg F)/(7989'/lOO) = 1.252 deQ F/IOO' Formation temperature was calculated in this manner and is posted on the log (Exhibit 4.1 -- see pocket) to the- left of the depth track. Each of the raw data values used for the calculations indicated above is presented in tabular form herewith in Table 1. .;, i -- I I Temperature RESISTIVITY OF SALINE SOLUTIONS ¡ 450 of I I Rw, Rm or Rmf I ohm-meters PPM 10 NaCl 9 8 275 7 200 6 300 5 400 4 500 600 3 700 800 900 2 1000 2000 1 3000 0.9 4000 5000 6000 7000 8000 10000 20000 100 30000 40000 90 50000 60000 80000 80 100000 f 150000 200000 70 300000 I i j 1 ì I ! j I : t I : I I i ~ 60 Equivalent NaCl in PPM 1.645 x ppm Cl = ppm NaCl 50 Exhibil3 ·: I ,- 17 61°15' lSOO45' I ~ 4 MIL[S . r,..,.. ~ ( <V(\) ~ ;rÞ-.) ~ ~f\{'" 1~C~(, '~X::' r'£~'r ROAD CLASS,Ç"!CATlOti i:_ !.W':'OUR IP:'! fRVAl ~-- . !"..,7 COOK INLET LEWIS RIVER GAS FIELD TOP BELUGA ALASKA DISTRICT Uruop\ 011" c.... Onl.tO" "".W1.rn. ~~.on UNOCAL~ 28 ) .. ... te.... . - ~)- . . í . t</~ Cr ~et " 2~ C.N",J~ ft:c- O~ fJ'-ockv''J uJe-J @ fr.v-lly vt:/e.k, :i,) ,s/r/'J 37= - 3 h 0 ¿"J dr/~ .3'llò- :?7«CJ 1 Of 13 e) t¡ ¿;.., ~ 'Lj..J Wdj¿~ ~"1")c-, r-ro~ó~ &//5 /W ~"" /,Ie. ú../r",J Ço-y/eJ. ØlJ J ..dIe-led ~ ¿. 2-0 ~/'_ /f/c.<.<:./ ee 1,1v~/~1--I: . . , ! , .' ~ r,j \ \ I ~ ~ ~ ~ '-< ~ K r- t--. I s.. ..-¡¡ ...... ~ I ~ 0 I ! i(' 1::- I~ .-- FORM NO 9-1904- A SITE PUr"). SR- 14 ,. \0 - '2 \)DDß ,--\ .~ r::¡ \, - 2'0.:) 0 l(3 (:" ,-- 2,.2- ) (. 7.(,. Dote _____ R e (0 rd ed by __\ (_. --;i_j.~~ · ~¡ fj .S-;~ U S DEPT OF THE INTERIOR GEOLOGICAL SURVEY WATER RESOURCES DIVISION GROUND WATER SITE INVENTORY SITE SCHEDULE / _ English _ Metric Units Check One GENERAL SITE DATA (0) Site ldent NolG1/1 \ I~ 1317 j IIS-I 1.0.0.115: 0 I f RG Number ~ Transaction [1;:] c9 D M V E 19 . .dd. d.'.I.. modify. nrifi.d r:-l . )r;1 Diu I 3 Ie ~ L M ';1 Reporting r;:-II \ '" C; S r:1 Site-Type L2.:.J C D H M P T (W/I.::JReliability =. ~ L.:.J Agency L.:::.J V,'- I I I Ô colle-ctor. drain, sinkhole, connector, multiple, pond. tunnel or, well field checked. unchecked. location not, minimal _II oIwh .ccur.U du. G] Diltrict~ State~ f:t:~n) PrO l'CI No [ 50 ~I ~ l L ,1 ! liS-; J iDC'!/ tS~ o Longitude I / , I I r, i'7 7 r;l : l'1 : I'; ::>. L.:.J d.. min Lat· Long 11 1 - ! S F r T '\ M I * ! Accuracy - I ~~ sec, 5 sec. 10 sec, Min ; Latitude d.g min Local '7---¡;:-~--·--;;"'· n.,:-- ------:-~-~~ L~nd --k <- NLlmher..12o ..~.1ErJJj\ AI'ViI10¡OIL¡Dl()_LÇ~&LLL_LIO,(_.I, *J L;~c2..~-=l-;/E';JIf' . t/4 1/4 ~~:~:t'on [14,11¡'·'(fJ¡f.,bl I~l-¡-::'i L 1 .L~L-L.L~L¡i:{~-jlT~ C ,t: S ,0,4 . T 01JA'L~¿~.D 1 O'i) 1/4 section, township. lange. Scale l~.5 =1 (,-: I;'lf-~-~ :c:: i * 1 .'-"" I J merld : AIt,tud" I 1 6 . ';'{1 {Ì¡.! ,- ..l-_~ Method of i _ r - A -- . -L ~ ;ll Measurement L2.7_ ~ L.__ _ ._~~..l......, :altimeter, le\o'cl. map r1 8 =~ (\ 1-;] Accuracy ::.L'-/~ , I . T opo r 19 c 1 : SPiting L I . ~_~_ .------. n -Cil- T U V W * ~~~;~I~~cDC' [!~ l S~.(j~.é'IC~~ I'd * ! swarT'p, offshore, pediment. hillside, terrace. undulating, 'Ialley. upland flat drè'o"i ;: [-;j]~~_:~;-~=j~G__ ~_ ø M P R ST· U (ii) X ¡ *' I (' anode, drain, goo- seismic. heat, obs.erv- mine. ailor, recharge, repress, teu. unused. with- waste, destroyed thermal reset'" aHan, gas drawal. C H K D deµ,eUIOI1, dune~. fla1, hilltop. Sink c:h.annel D",· of ~"sr Conqruct,on : 2 1 Completion J J 4 ) ~(-'.7.L#~J I}¡,! !lh d~ '1 Use of V'¡d1l'r : 24 -__~ ~-~._~. ~~._=-~~~ . eN) P ~R--;-~---u~~R file, dc.mesllc, irrigatIon, medicinal. Industrtal, public. recreation, stock, institution, unused, desal. other A C D all C(,rld botfllf1g. commercIal, dt-'h-atf'r. pov.t:r, suppiy So t<D I I . urce 0 . 2 9 0 lJ * Depth Data I I" S"cundarl Wil1f~r US( r '7" "1 2 5 _;_.;.~! ~ , Tertl_ry Us,'! 26 = ' of 1/~;a1cr I I I I . * ¡ ¡ ; 11 Depth of. 2 7 I I . H"lf 0 i ~~. . ---:;1 Depth of i~-.:-T , '-' :ï () . I , ! ¡Well I 28- ! 2, I i «:,. . i \\é:t1f.'r Level ;;;-r- --.~___r;l ! J j [6 ..! 1 .J_ J tî'\ , 3 3 = iLl * ! Sou rce '-'/ I ;. C' -: /I ¡ *! I."II ~ ¡ Dòtd.1eallHed ~ 3 ,_ ! 111-/ J ft¿/ month day year f\..'¡pthnd of MCd!iUn'ml'nl ,3401 A C ~ -----~--. M V z * R T G H ----------- ðlrl1f1(·, Cðll¡'rdlPd lIHhnf' pr8S$u.e. ca:tbrated. geophys-'C-i;I. manome1er. reponecJ. ste-eL electric, caltbrated. gagp pressure ~gf' logs tape tape elect!'"ic tape other es1 'n].:=:tðd Site Status , 37 r - . D - ------------------------~- ø V x z * otner 'Y i'i :rf3== * Measuring 267= * Point Date month day R H T G - --------- - ----------- dr V flo.....,ng. n6drby. flowlrMj ohrtructl;:Jn. pumping. recentiy. n~rby, nearby. for€lgr. surface water pumped pumping re-centl.,. substance effects pumped nearb'( recently flowIng Source of (1 ' Gr,ohydrolog'c Dat~··' T -1 1. I I Measuring Point 3 6 ~ Pump Used ~5 0j_,-*~ 2660 O:,'NrR IDENTIFICATION 111 I R = 1581~ [~J!\) D M ~ .dd. d.I.I.. modify Name: Last ~:lr~r:-, . , ~,'~ I ;í.JN:T ,Ll Datel)f. ~ I ~V·/' 1/ I ú - AI-:l Ownership L..:..::.:..:.J . I _ I Lf I J I II n:.J month d.y yur EJ First f162:lrfT ~. ¡ *1 1* i i ì Middle Initial 163 = ¡ OTHER SITE IDENTIFICATION NUMBERS (11 IR= 1891*\ [~;:]~ D M G arid deletf'. moddy Ident ~b(), \ ' Ident~'2.0r)lhI81 G Assigner ¡ 19' = irrr, ,i1\ Pi ~ Assigner ~p" V; J\ (y-, j* ! j *! r------.---- ì , New C.rd Samp R & T : SITE VISIT Df,TA (11 IR=186ß GAD Dat,e of B VISit G M I~ ~ear~:nOf :18-8= 1-,....L " ;..l --=. ·~?7~B.~::;¡ I / month / day year anc. df:'lett!. moddy FIE LD WAHR QUALITY MEASUREMEN1S (1) IR=1921*1 1 T= I ADM 1*1 Date §:!] G Geohydro· ! 1 9 5 t logIc Unit I :* / / New Card SamE R thru 19G add. dE"letE'. modlf" month r,;;;¡1o 0 0 " or;1 Temperature ~ I I , . L.:.J Conductance §I 0 I 0, 0 I 9 I 5 0 B !l Mhos day year c11g70! Degrees , I. *1 I · Î , I· ! *1 ,. I I * I I. I I * I Other (STORET) 8 Parameter Value I t97 0 I EJ ~ Other (STORETI r,;;¡fl Parameter ~ Value 1197 0 I FOOT NOTES CD Source of Data Codes D G z ø A R reporting. dt,lIer.o.....ner. other go,,'t. other log! geologl'5t. other .agpnc y reported well No. .'---- Latítude-Ion2itude N S d d HYDROGEOLOGIC CAR D I J Physiographic r SAME AS ON MASTER CARD ~: ?2/fC/F/C »;17/'-1 Sf/5/ I ., . I c.' ~~:~~~Re ¿J ~t.t/ 6¡q .e. 22 l:2-:9 I Section: 20 21 I BiD: BI~: 23 25 éOO/C- ~/vCé-/ o Topo of well site: (D) (C) (B) (P) (R) (K) (L) depression. øtream channel, duneø. flat. hilltop, sink, swamp, (t) (p) (8) (T) (U) (V) offshore, pediment. hillside, terrace, undulating, valley flat /I/¿¿5/06 .27~ I ð :Cf- J 30 1 MAJOR AQUIFER: rjJu ri T6£¡1/;¡Ø/ system c;.., . 5et) S J ¡ r .¡ , u t1lWm AQUIFER: 37 I LenRth of , well open to: /déU/'/T I Q:R- ( 6ú9Cll7i, UND/J=-F serles 2. 29 aqu~fer, formation, group Cia)} ~ Q!.!ili: 6ú1CJAl- I;? I ~ss: [ I . ] Depth to 3) it 3'~O top of: , I ft LitholoKY: ft L.,LiuJ I I 46 41 øyøtem serieø U 45 L.Í-4J ~: ft I 54 Lithology: aquifer, formation, group O Aquifer Thickness: 50 ft I Length of well open to: 53 I Depth to 56 . top of: ft f 5 Intervals Screened: ~ consoIIdated rock: 57 S!I ft L60 ¡ : 63J Source of data: ft t ¡ : I Source of data: 65 61 [ i ] Infiltration 70-'-71 characterist1.cs: I I Coefficient L : : J gpd/ft , ~: 16..J--J..7I 73 75 gpd/ft2; Spec cap: gpro/ft; Nùmber of geologic cards: -------0 79 Depth to þasement: Surficial ID4terial: Coefficient Trans: Coefficient ~: uO 690 720 /v-Or ¿OUJ /f 50CJd (!16¿DS - wYJ TGIZ- tA/~J-L, - 6-06S DJZY. ¿ðr5-S I I I J I I ~ : I ---T---+---~--- I J I I I t I I I ---~-- --¡..--- I I I I I I I I I --- r----~-- -t--- I I ~ø I I . I , ~ ~ .... fl6GP ¿,V¿:-¿¿ TLJ /3 ¿'- ¿;///I./T&I¿. 1?7éf-7S bf- /Tv/fit.., /9 BI-rÇ- j)) I- T¿:" ('? ~- (.)) / / ;../ ¿ ¿ /-;<.:J .\/ .2) /¿/ C. ¿ GD :ZS" (ß/L-L /J/¿; A///-I5 /~/2â/:-/ 2: o ~)¿ --1/ -' . 1 ^ /7ì ./7,( / ·'1 /~ .~ . . -;- //,/':;'-'/7/ / ">/-:'/" -/ // [ / f GPO ~37·tu rz -71- :':]ATER L1Èt'L DRILLERS LOG ~ Dù-~OT FILL IN Drilling Co. '¡¿f2.A~I3u~ V~G- I Drilleir72rtN IL , 'Ptfl~ ~{j t.t:rG~ ¡leU olmerD~ /ll.o ~ ~l.^ ^' ..t....-:..A\J.~ I USGS 1'10. j Area Usa of Well Location (address of: TO\'ffiship, Range. & Section (if known); distance from road: ~ ~ ('''9 Q~") * / Sizß of cas~~DePth of Hol~JCfeet. Cased to ~ J ~ feet. Static water level 1;1 feet Cabo~a} (below) l~'d surface. Finish of well (check one) Open enå (): Screen ( ): Perforated' (~ , I . /--:J { .·17 4- ' /0 Describe screen or perforations~~ /03- JêlO. J3t.-/YìJ'f~-JSlf. t1ell pumping test åt ~ ,5 gallons p . (min) for hours ith ~ Ò feet of drawàowll from static level. Remarks Depth in feet froIJ ground surface WELL LOG Give etails of formations penetrated, size of material, color, and hardness. .1L to L ...L. to .l.1s.- R to .li ~ to .31 .:1!L to Q Mto~ ~ to .:J.:i 1..1- to ~ 8 5 to.1..D.5. /fJ,5 to/&.. /.:11l.. to IJb.. /.M.a.. to 'l!£t1 J.!i.1l to m. Jll to ili 1M to l.f21J. L~ () to ill ' -l~Q JL:: -~~ . (\ a .Â-.... ~.. tl- ~.~ ry... l\J CL ( l ~t\._A_ J i~~ __Í\n "^ () Lt~-h-^ I ~,../'^- ~ (ð \') P /n ) J / /L....·-<.\ ~ L . ...(\ Q ~" \S tS/ ) {J\"ßtl\ OAI\lÅ~Q l~60Î1\ () I ~Q:::~\~~~~ ~ UH\~) (~ll^~~n~1~1~~O~F¡-J 35 ¡hi) ~t-""'~~~L\ -~'~~ ! ~ ~ ~~u ~ '( ~ ~ V' ~) ~ --- f) ..-......J ~ ~ D fORM NO 9- 1904- A .'- SITt-rlO. Sß- \Li-9-ss AC B D .1-' A-k - ')OOCc:¡ Dote Jl.:l~_-l~~ R e ( 0 r de d by _1 \.) \'\ d. r \ \ us DEPT Of THE INTERIOR GEOLOGICAL SURVEY WATER RESOURCES DIVISION GROUND WATER SITE INVENTORY SITE SCHEDULE / _ EnglIsh Met", UnIts Check One ~ \J "" GENERAl. SITE DATA (OJ Site Ident Notc~1 II'S 1L ll! \ S, C\S,~.3 19101 II 3 t9 r:-l D H M P T ~ Datal 3 = I c cW l Site·Type L2.:...1 C '-",'l:.JReliability coll.ctor. dr. in. sinkhole, connector, multiple, pond, tunnel or, well fi.ld ch.cked. unch.cked, locltion not. minim.' we" shott .ccur... dot. ¡~l .. ~6= î:. ~. County 1 .J Dlstflct~ State~ (or town) ~ RG Number ~ Transaction [!:;] @ D M V E .dd, del.te, modify. verilied M 1;1 Reporting ~I,) (. r.... <: 1-;1 L.:J Agency L.::.:...l ,~I' I --' L:J ProJect No [ ~ I G 1 1 ~ il S.o;SS ;5,91~ d.g ¡ell:1 S¡¿117~ d.g min B longitude lat long . ... f"V'I ' * J. Accuracy ,2 1 ~ . _S__~ _~~...LJ sec, 5 S~, 10 sec, Min latitude min 1.0[,11 Numher 1 2 ~ location r M"p [14 Altltud, r 16 L .. _ . . ... _________ _____, land .________~- ___________~_._______. -_-_- ...___~ '.S¡gIO! ) A D 10. Q,'S!51/\Ctß tDJ. L_LLOj)J~~ ~: .1_3 = iNW. ~.bJfJ-E.~_1'S.31" T _OJf1}J-L_. RI\~Jj)!·t_iSl~J . 1/4 1/4 1(4 Sf:ctIQn. township, range. mpr,d c IT ¡'YID¡f'Jl ¡K j IB'-I~ _.1 -'--J.._~ 1 ~.~. f:! }·:1~ Scal.. ~1GJ~31~i) lH.J~ AQ =-.~J~ altimeter. Ip..el. r~ 8 _ r - -----T;l AccuracyL _ _..i-"L_L~ k,¡COjO! 1 :t 1 Method of Î ¡ I J Measurement ~ 7 ~ ; 0 C @ H K " Topo r- Settiog l 19 - - -~-~--==-V= _v~_';' ~,~~:oi~~~cDC) G~=TI .~ ,O_l2_LQ-Þlc¿-iI~ df'P't'~~I(III. c1l1ÍJ~~. flat, h;ll~úp. ~,nl. s.....arr,p. offst.ut£. pf"dirTlent, hõlls.rde. terrace. undula1lng. ""alley. uplarJo ch.anr1('1 flat dr~.·.- ¡ D;·t.· of first ! Con~trurtl(ln , COlnph·tlOI1 ·b~ n 11,. ] Use 21 0 D I G of 23 ::"J A 0 ¡ L." ¡ S,te nl'.' III h d.t"- 'r eiH anode, dralf'-:. -~- ---- ------ ------------ -- -- --.---------------------, G H ø M..0 R S T U W X z i*\ geo -s~;;'jc. -¡,;;t.- ~b~;;-~ mine oi! ~~-:-r-~-h;;~r-e-~-t-est. unused~-~I-ih---~:a~t~~ ~~-;~~ !h'_'frnal resen ðtlQrl, gas drawa!, ---- r l 24 -- ------- ---- --------~--- ----,-~ _~_~~ U Y 1*: Use· 01 \\ att' M N R D c H A B -~-----------~-- '" Ir cone! bc¡Ullng. corr.mO(la!. dfo.....ater. po.....er. fHE. domestIc, Ifrigat¡or~, medlcmal, Industrial, pub!ic. recreatIon. ~!ock, institution, ....../1- suppl) Tertiary Use r,-2 6 c 1 : ~ l' ~ Depth ofi.-2 7fJ¡ '·-·2 0-2·· ·-5--- : >I-! Depth of I-----~ .---~~: "I Water "------..L....L::J Hol, ~_.._~, , , .. I ¡ ¡Well ! 28 -. j : I . '.; : 1 I G). ----,--.-- Source of I 2 9 - I ; >!- Depth Data - 1 : unu!ied. desai, other Secondary Wat'" Us, 1 2 5 0 1 r , ¡ . j L_, Watl" l.e,,.1 ~~1·--~- 1* ] 3 1 / '" (ï'.!33c ¡ Ii 1 Date ~\o-1E:asured -'-------""-- Sou rce - '-_n ~-~ month day year G H M R T V * , e r"t'1I H_ (j of r\o-·i!,:.t,>tHPrnent .34:../; C ---- - ---~--- ~tlm?~ed, pressure. C2l1brated. geophysical, rnaoomete-'. reportecf. ste.::-I. eit>-C1rlc. calibrated, CI~he:- gag€- P'"e:.sc:r~ g¿g'- log$ tape tap~ eitocrri.c tdp~ ~rri1rh aidm.,: S,t! St<ttu~ : 37 c '-0 ------~---- ø v x >I- R T G H --- --- --- ----------~- dr -... Ilo....-uioy iJearhy, flowll~ ne.~~L'r'. obS1rLctl'Jn. p,-,mpllì9 reu·ntl,.. nearby. nearby_ forelgl} sudan' .....ater o.het" rl'centl, pumped pumping recently substancE effects flo....¡nq pumped :;'-]'s-==-y -X 267~ 0 I ~ \:) \ q (~ i..*_ Source of (í, f 3·6.' T.iRJ-_l. *. '_; G:ohydrologlc Data - _ f\1ea5Urlil9 POlOt Date Pump Used _3 5 ~ i~*__ r.1e~~~~\ng~~~ _ - I .t1_.__-,-~ month da'r' y¿a~ O\'INER IDU..:TIFICATlO/l; (1) IR=158~ ~I® D M ~ .dd. delet.. modily Name: Last ~h,~,L ß.o IJ ;¡-;ý, Date.,f. ~^ 7/Æ\ D / lOr. qr;1 Ownership ~ I L/ I . L.! I~ I 'L.:J month d.y yeer , 1 62= 10 in L r 0 .--:;¡ First I 1 ~~~~_-"---.L~ ¡-·············EJ ::::.:::::-:::::-:::::-::::: * . . ...t...t. ··1· .. Middle ii 63 = 'notial I '*. OTHER SITE IDENTIFICATION NUMBERS (1) IR=1890 w0 D M 0 'dent~hD ,} , Ident~:l,é),D,bI7, G ¡ 1 9 1 ~ ! þ: rcq'J Assigner . : ,'(. , . >!-, arid deleu', modi"" ~ ~Tf' r·· r Assigner ; -.... /.. ~ <.. ,\...7 -------~------ -~ *1 -~ r- . NplN Card Sitme R & T : SITE VISIT DATA '11 IR=186ß GA D 13 Dat.e of §I VISit MGJ --- - ------ 188= 1 Name of Person , / month / - ,--; ---"- -"----....;.---~ ...;... -'- d.y y..r ddd d,- r-I" n',odll-.- fiELD WATER QUALITY MEASUREI\1Er-.:TS (11 IR=1921*\ \ T= I ADM 1*1 Date ~ 13 / Geohydro . 1 9 5 ;; logIc Unit / i* i,C_ - Ñ{'w -End S-anle R thru 195 . add df'l!'tf'. morltf,· month r,;;¡¡1 0 0 0 1 0 r;1 Temperature ~I I , 1 I L:.J Conductance B 0 I 0 I 0 1 9 1 5 0 1197 ~! u Mhos dð', year Degrees CI197 ~ i Value 1197 = ¡ ,,. I I. ! *1 i: *. I ¡. . I · Other (STORET) ~I Parameter EJ EJ Other (STORET) r,;;j¡l Parameter ~ Value I t97 =! ! * I , . I FOOT NOTES· G) Source 01 Data Codes o G z ' o A R L ft'fXJrtu'Kj d dl('r.ùwnf'~ ùth.., go..', otht!'" logos 9;:'doº'~! othe~ ~ell Mo. .- -' Latitude-lon2itude N S d m . d m . HYDROGEOLOGIC CAR D I SAME AS ON MASTER CARD I I' f"/ì ira~naRe lS:...J ~: 22 Physiographic . I ;9 I ~: ?#C///C ø/?/v' ~<;{/5.r & 1 ~: . 20 21 7~-t?vðe~ ðv" I B ¡ tJ : i? I~: 23 25 CéJéJJC- P-/¿~T o Topo of vell site: (D) (C) (I) (F) (R) (K) (L) depression, stream channel, dunes, flat, hilltop, sink, swamp, (.) (P) (8) (T) (U) (V) offshore, pediment, hillside, terrace, undulating, valley flat .27D , : I 30 31 ~ ~~: system Li thology: f Length of to: veIl open )5 31 twiQß AQUIFER: system ~~: I Length of 51 well open to: 53 Intervals ~: series : 1 2. 2' c:I:J ~: L I : J Depth to ft 3...l-.i....O top of: I I aquifer, formation, group D Aquifer Thickness: 3. ft ft L.1.L.i.3J I : I series .. .5 L.1-.J Origin: aquifer, formation, group D Aquifer Thickness: 50 ft I .6 .7 ft 59 I Depth to 56 .~: ft I 5. 51 DeDth to consol1dated rock: / ! ~J Source of data: t Source of data: 6. Infiltration characteristics: .Z;lf//:7¿ Z:/VL>. ¿L:J6- 6.[£] 69D 720 Depth to þasement: Surficial ~: Coefficient Trans: Coefficient ~: ¡tfj¡O' r:.172a,~t Lto : ß ft I ¡ 65 L10J.11J gpd/ft I 15 r Coefficient Storage: 13 gpd/ft2; ~: L16.LL 1.J NUmber of geologic cards: _______r::::J 19 gpm/ft; SrpON6k, B-3 r{Juytj). -i:~~ 2B t-~:---t l~: ". I I ~~ - -~==- -- ¿.. +~ 33 G~. .35~ T/~ ¿ C;;{--{// : i I I ~ 1 1 I I ---T-- - + ---f---- : I í:"\ I I I~ I I----~-- --~_-- I I I I : : I ~---r_---~-- ...1___ I I I I I : ~ : I :E: ~ .... ~ ~ -__1- 2: o 3S ST/-}Tt/S (~,Ç AAI!!) cJF ¿V/?T~ ?lj6L-C. t../N 1: /ý 0'/./ //. ¿;;/L ?!J6- ::-J-!eJU..J5 /7'/6-# É~5-:::.~_:rl{//Tj/ ¿)OWN 7"/2 &.s /7' to /'9 T~.;e. 70 /:3 06" ¿O{fl~}¿ /~S/ST/¡//TYTO /9/ð' ~TOP E:rþ~tJ~) //a5~ 2/3Lf' ~é/;er .....r;j~¿/A/6- ¿/.//~T6£? GP 0 937.1·42 I: ¡ ,I I ~!' . i I ; /12 .¿..., I '·c....t' 1 ( II I j ,I, II. , 24\~" ) l ---..---..-.---,....-.. .-.-.-."--. "13 . w I I .,\ 0'''''' , ,..0, I;' \ '", ,.\~._.n_\ \ ï' ) "\ ~\ " I \" ---:- y. '\ ""I, 36 31· " ~~. '.. - J+- ~~ '"--'- ~A ~ ~ ISI° I i ~"'JI}'Î \ 'I: , 6 S VABM 1'1 'N :'~----(:¡YONÈ-K A'-~.?~~tP 'f- r::C1.-··C-.F~··l -: J:--,{ 'J 1()()(1 'J 1 ¡. 6000 ._¡.c-"-[-:-.-_.J.~ -{ I :-.-.=--,, -:. '. ,~' I "', ( \ 15 N / I I 14 ~ Ii? " 8 ) fl\.¿ I"~'\\,~ " I\, <.'<'0 \, <?' 10 "" ~ /<>, '_"."_'_' 1 ·12.,'~·.iJ ,', .~:~~': "" "'~.,\ 2{' , J~~\'19 (it) J ('~J ", ,I·,,!, L .", .', \ fi r',\ I '_.)'J, I \ \ .\IJ, _/~ I ,Ii, (,,,,""., . ~ .,,,'. r '. S 21. '., (\./ 20 . .----- j~--_._._--,_._-_._. OJ" I' \.. , \ 1\ Y21 , " 25 '/1 [, ) ~30 .q -? , . ~ \ "\ \ 28 1,1 \,.~ . , ) i? , - Z, f" -~-~~:~'i~-t:-~+--:- , . ) '. _.~( 1 ( '~ ' Winter ( Gra':lts' La" jng Stll~ .-,ç~~~ .'36 ,27 26, 0:> ,...J I ':-'J .,..;::\,'''" \ I ". :~fi r' \ ç.' teU;\8 R! r" ..^ " 31 SlQlIg.~."32 r """I "" ~--~ I- .,,~ 0'., 6794000m, N. '32 I 35 lCheda ~ VA~~' . ThPOd()t'e'~ 33 Lake S I .. . . -bins ..,0.,. '.J n a T lJ \0 ¡ , [ 2. I 1'6T6ooom'-l5k---4 INTE¡q'OR -,GEOLOGICAL SURIIEv WASHI""GTON 0 C - 1V07 r, 9 W R 8 '^ 4 I "_L ,__.....l:-:: . 6,-·^ "-..-,r 5 µ 13 N --' 61 IS' 150'45 SCAI_t lfj~ 360 /' -^ t- 0"1.- <'"i-- t, MILY"l "I. :' 'I f1 ROAD CLASSIFICATION -,r j ~: ".ILCH·1fTlr~s No rQads or trails in this area ., 4 . - "I " - -:-.;"~ ~" .,).... CONTCur~ INfERVAL JOO FEET DOTTeD LINES RErRE';UJT ~r¡ r (\fH CONTOURS DATilr·1 I', r,HMI Sf A I LVU .~ FOR SALE BY U. S. GEOLOGICAL SURVEY FAIRBANKS, ALASKA 99701. DENVER, COLORADO 80225, OR WASHINGTON, D. C. 20242 A FOLDER DESCRIBING TOPOGRAPHIC MAPS AND SYMBOLS IS AVAILABLE ON REQUEST QUADRANGLE LOCATION TYONEK (B-3). ALASKA N611S-WI504S/1SX225 1958. MINllf~ I,'t \"",1/ )~, ', 1 '¡hll FOR SALE BY U. S. GEOLOGICAL SU FAIRBANKS. ALASKA 99701. DENVER. COLORADO 80225. OR A FOLDER DESCRIBING TOPOGRAPHIC MAPS AND SYMBOLS I 10".11',', J' ¡_.,r,' I~.'d r·.~· .If,.1 j'I[. t!l~ ....,....!te' Jft'J" iJ,,'_J,11Iy . '! I -"" ,pIp'! .". Ir.!f-:'r~.rl'!l·1 t· :rn !pflJI ;_··h-_H.:~' "ph..:, LInd I,',,;·, '''pre',f''t un<,u,',eyed dnd 'Jnmdrked IOCdtlons ¡jrr'ck·terrfiH,,·~,1 L'I ttlt~ AIJfè.:1U ljf L.1rtd Mdr1dgerner¡t F, ¡j¡,) S 13. 'Jew.Hd MefldlJn ,¡ 266000J I I ':~ / FEETl . . / "·'>...29 _ -., I 28 I (I. '. . : ·'--_~·!;lr 8..f... ' -< 462 ~. - ,- "-." _ _ I·· / '-, I - , ':. i I f--" ': I ' I' ., !.. ZOO-' f' . . ), L' .- ,- " /-~·r "- : . I - 32 C", 33 34 - J ~- 35 I· 36 I . " . ¡ - ~ I ~'---.. ~ : J ' . í '0 ^ . g ~ '.. . . f~----- I___--L_-!!~ ""''!A-SUS'!''A ~",l",>Lb'!. Buf ---_J_ ¿_- J 4,",> - \1 KE~AI PENINSULA. BOR&iŒ'i BV. 2 ' ~ r 11'~ 5 I 4 . I 3 1-' f' '! Y .¡' 61 15 ' I " I . _/ 'BEL UGA ~ J 151'ono" 5' 131000JFEET I 1510 ¡,.\ Mapped, edited, and published by the Geological Survey of- ¡:.: Control by USGS, USC&GS JnO USCE ~~ TIJµO;¡<JDhy by µhoto~/,lmmetric method5 from aerial photographs ~ 0 Liken ¡ ')52, 1,<:I,j ,¡rlll:)tat~rJ 19,,8 Map n,)t field checked ...." LJnlvt'rS,,1 r,,¡IIs',p,,-t' MerCdtor p,c¡ecti)n 1927 North American ddtum Iù,UClO fj'Jt gr,,j I'.,·,,·,1l¡n AIJ' I", ,·,)ùr¡J",dte ,;y~t"r·. zO'le 4 1000 mder tJrllv(>/';,¡1 rrJ/;s...er·,e Mercator grid ticks. !,}~1e 5. ',!llì-.'ln III bldt' CONTOUR INTERVAL 100 FEET DOTTED LINES REPRESENT 50 FOOT COI/TOURS DATU/·j IS /~EAN SEA LEVEL ~I j25V.~:.(: is¡ ~ z, ~ ~ Ii p!:! /1 APPROXIMATE /,1EAN DECLiNATION,1958 F=i;-~..=:J 12C'={) ~ '3 ~ ====r ====r ====r 3000 ===--r: 9000 6WO ~ ;CŒ E3::=:::=3 55 fTYON£K A-3J SCALE l:6336Q 5 VABM , 77 ¡.{fid; (, - 6· .. 30 ·i' f ; i f ~- \ il - ~D- j -'~'~', ! ,,,' i '.,<'> ~ ¡ \, i ì "\ \, 15 \ , '~~ ì 1 . ( .", -~-~~-. 26~:, ,- 27 I I ¡ "~- ~ r /1/, 21:---~/ I~ .-' I .~ . . \..... 22 ,/~ ¡. _ ;~ , '~, ,., .-:. . I I; 20 24" I I t: i (~f~ ~4\~ I \ 0 j .Q' ! '. (';) r ..::'*- ,1'5> ""~Þ ~'0¿",· . I '¿ t ''\~ l. t I ." 75<:'\' ì \, --,/ '\.'\.... \1-7 ~ " ; 17 \\ B ~'---.. / ì8 ·13'- 14 15 .+ . r 8 t-. --¡ 9 ¡ 12 i! --!,J j ,=- ~~-,; !i ~, ¡ r .., ! ! i ¡ ! f lø J' -W ! ¡ , L': . ¡ ;.-- 4' .Ρ ÇJ 20' f-~ , :!:. 5 ' "J 0 ~J'-" - I .-.J~) ~I ~I i D <r! CJ' -~ 0 ~ '_~,::P - .=t '5 ø 32 . ;J:Z¡'~. ...~J '. ''--.'/ -(_ _ 33- - J C' - I ¡ ,'I , ~J ~,-; <:"] .:<55. t i' -::' ;J c~ 3Ò~ ~-----~-T- J t ·l Ci .1,._ 29 1- - -Q, J [,~l () J,,?~ ," 25 28 , 90Q '. le\..- q , (. _~ ~_ c·ò· ~ .' i" / g- ).1 \ . /\ {j .. '··d L ~ 1.j "-; 15 '. 32 'J ~ ~[T t , '/ ~ I- 'f:, fORM NO 9- 1904.- A SIT___b -St- ~k )~-9- ').. ('j £5 DG~- , -)0079 Dot e -.L).. - J2-=.I Cr Rf'((),dl,'d by L- vf\Je \ \ U S DEPT OF THE INTERIOR GEOLOGICAL SURVEY WATER RESOURCES DIVISION GROUND WATER SITE INVENTORY SITE SCHEDULE Check One -LEng'ISh Metric Units c. ~ 0 I .~, .0 t-- ~ ~ D.L ~ )¡,¿ '0 ;GEr\¡¡ RAL SITE DATA (0) she Ident No ~ I II \ Iq A ,1! I S~OIC)IO Âlq b ,21 RG Number ~ 1<; Transaction ~I (À) 0 M V E edd. delete, modify, verified Reporting r;:-\J c. r..., <::. r;l Agency L.:.:.J ,- t:: I ~ I L:.I Si1e-Type G C 0 H M T (WERelia~~~13= ¡ C (U) L M EJ coll.ctor, drain. sinkhole, connector, multiple, pond. tunnel or, well field checked. unchecked.locltion not, minim.. well wit e..ure" dete 1*1 . _ ~ 7-101-)0 County 50 _ J...L 1 L I I J I 1 L_j Distnct~ State - ~ (ortownl____.___ _ PrOWLI No ~ Latitude G :&'1: I,Cf¡4IlE] B Longitude : I l-=- 0 ; t:' 0 ;L; () r;l I Q I :...11 ~ 'I \ L:J deg min deg min lat·long¡ I ~ E Accuracy l2_1 =jS__F T_!~. J sec. 5 sec. 10 sec. M In Locallon r Mdl' ¡ 14 h¡YiOI~I[ !K 8.'-15>1 ~ -.....- 1/4 177: : - . ::~;-] 1~_::r ··I:Y ·c:··<--> land Nel loc. 1 3 ~!£1_=_Ð]1j~~_~~rS-) ,'1 !_~<ÞJ~2f]J ~-_~~.lho~~lW : s~~J lOLal Numh,·r 1 2 = 'S!BrS~rIL6~~ Pi !O,');c,ß-¡þ~c.~-:_15=oJ~~J 114 1/4 sectIOn, township. '-~------'-T-l Scale ~_~:JC;3!SJ.br\ _L~ rangf', melld Al1d"d. l 16 . : I Tþ¡:~ -. ] *J Method of r - 1 - ~ --~ - - - T-, Measurem"n! L.! 7 =; _~__. ~~ _~_"" l~ alt1mpter, I('vel, map ~- ·U·--'- i 18.· i * : AccuracYL:..n. L "...L--,-__ T(Jpo SettIng r 19 l D C (2 - E F H rh'flf:'!. .:>.1 hdl10P ø T u V W ~ * ~~~;Oi~~~C) L201 \ ,C¡ ,0_ L5 :ojj ,f) ~i1~ undl.=¡~t~ng. ..alley. UP!,l!iG flat dra.', dt'PU'HIIH1. ,1rÐan offstllHt'". pedlmE-r;t. hdlslde Cho1f1 r,p: D.1tt of FirS{ C( r-,~truct {}n -.--_ Conlplt,tloP 21 Þ b D,D \~b,CZ~;ì Use r--------r ~ ---- ---------.--- --- -~-- --~--- ---- of 23= I A D E G H ~___r>.~_Q) _ _~ ___~_ __!.._ ~_ ""'--.2<__~j Slle '-- - -.1 anode. d,~~~-g-~:- seis~Tc~-h~~t.- obsefv- mine. oil 0'_ rechargf. repress, test, unused. wlth- waste, destroyed rh(::maf atlOll. gas dra....al, d~ y --~~-- ----~~--~------ ------------------- U~.· of "..~ d t (" r . 2/j A B c D H r>.~ N R T u y z ~-~l ---~ ---_._~--._-_._------------------ ------- 011' co '\d . bUlllrllg co~rr.f!'(lal Ot·...2!E". powf-', fire. domestic, Irrtgation, medlclna!. Ind:.J5triai. public, recreat:Qn. stock, institution suppl" unused, desai, other s,er:OfJrl.try ~·i~ITt·, USP 25 - ; :+ ~ T'rll",YUS"¡·26.-1 T~lDCPthof~.27:i ,. b.~S,-ì~DePthotj-;~:!- 01 Wdter L _.l---<---.J Hol, '- _ __1~ I .. , . ' , . Well ' ---~-----------.------; : . : ! * i CD Source of '2 9 = I Depth Data I , . : *: Wal.'r Lev..1 [?~-:T 1* I , .; _ l j j , 3 1 0 I Dak Measured _ _ _ -'- _1__ month ! I I . '*' '_ i ----.L-----.L_~~ day --------- ~.~dh()d of 1\1f'd\UH'nwnt ;34C~A_ C G H 1.1 R T v z . ilullfH C-.tJltr?tc-oç' l""'lnI,-ttx: pr~u'€. ecilbrated 9eophysl~!. rr..anometf'i. rep{)'1ed, steel, ej::ctnc, c.a!lbratf'd. othe-t ðlrl!nt' g.a~f' p¡-E'S.S-iHt:! g¿g'~ lo:?s tape tape elt"ctnc 1ao'- Sdt'Status 37 . T - D ---- - -- --- - --------- --- -------- G H ø R T v x . - ".---------------- dry. flowing. noarby, f 10""'-1 f)(j Sourrl' of í1'"' G<c"hydrulogl( Date r· 'þ1 _1 ~ ~ 6_j~ *_' ----r-"\~ Pump Used _3 5_~ l..:...*~ nærby, nBatby. foreign surface water othef pumping recently sübstanc€ effffts pu"'ped ~ Me~~~~;tng ~~_::.. '2 O~__~ ~/3,:::Y¥ ne¡,rb",_ rf'c~nrtr tlO""'rng obstructlun. pump~~g recentlv. pumped Measuring Point Date 267= * month d(!}' O\\NER IDENTIFICATION (1) ~ G(~ D M G ~~hiP~ICP /() It) / r:-;:-:-, edd, dele,., modify I· . .. . . . . .. . . . . r:l Nlme: List L~..~_:-'~ \" ID, IC¡I L I ,D t: <¡::::/:/::i:::::Ó LCi Þ ~l G month dey First 16~f\~L.- y..r I ! '. ~~~i~:e G 63 ; _--=--------i~__L_~~ ¡ *; OTHER SITE IDENTIFICATION NUMBERS (1¡ IR=1890 G~ D M G Ident~P, L- I B ¡ 191=!/I\\/vf\{J Assigner' ,1\[\,1'1,' ,* arid df'o ('te. modIfy - --, New Card Same R & T : Ident~'ÖIO,7r-1 ~ ~-~~------ * ! 191 = ' \ Assigner' !~.K\(G.,..; ;. . SITE VISIT D/,TA (1) R = 1 8 61~ ~I A D M I~ Dat.e of 1187#! VISit .Jdd. dt'I(OI~. rnllnd.., I / month / ß Name of Person 1 88= -- ....- -~ -~ --'--- day year FIELD ,',ATEFi QUALITY MEASUREMErliTS (11 IR=1921*1 I T= I ADM 1*1 Date ~ / / G Geohydro· : 1 9 5 ;; logic Unit ' * N,·" Card Same R th,u 195 add deletE: modd". month r,;;;1 0 0 0 1 0 r;1 Temperlture ~ I I I I L:.J , . ~ I~ da..,· yea~ Degrees C 11 97 ~ ¡ µ Mhos 1'97 =! Value I 197 ~ ¡ Value l,g7 = I : * I I· ! *1 I. ¡ ! * I . . I I * I Conductance 0 0 I 0 I 0 I 9 I 51~ Other (STORET) 0 Parameter Other (STORET) r,;;¡jl Parameter ~ FOOT NOTES j) Source 01 Data Codes D o A R G 'l'µ'::)"lr~ c·IIIl·f.o.....nf'f. oth~r gu.'t. other J{j9~ gt'.:,fu:; ~'. othe- ageflc..,· 'lI!!poned ~ " o - I n --1 =c c::L .~ o "'-. 'i"........ FORM NO 9-1904- A S ß - ) 'i -- q - J C g, Dc t - I ~k- )oD'71, Dot e -.l.~_=l ~_=-!~G_ '- SIT--.J R c ( 0 r d e d b y ~ 1- V'f\!l. r \l US DEPT. OF THE INTERIOR GEOLOGICAL SURVEY WATE:R RESOURCES DIVISiON GROUND WATER SITE INVENTORY SITE SCHEDULE vi __ E nghsh Metric Unots Che-ck One GENERAL SITE DATA (0) Si~ Ident No W 19 All j l ~ 10 r5IO,.:t /1 ;01 \ I RG Number ~ TranSKtion [!;] (Á) D M V E ~ 19 odd, dlIIIO, modify, Vlrifild ~ Sit~.TVpe [2;J C 0 H M T (w)1~Relia~~i~13= I C ® L M EJ Re:o~~~~BU,s Gs, 0 ~ collector, draín.IÎnkhole. connector, multiple. pond. tunnel or, well field checked, unchecked, loe.tion not, minim.1 J'- well.....ft accurate data (--. ~r: Oct 50 ILl I j I I lotj District~ State~ ~t:':.I_ :R: 'C'\ ~ Latitude , i G ~ (:, I I i I IC1 ¡¿¡ ,7 EJ o Longitude ! ( ISIO ¡ ;10;4/1 ~ lat· long: ! ~ ,11:'S F T M* Accuracv '---_.J._ ______ sec, 5!>eC. 10 sec. Min diU min diU min land lool . . - -'r;;;>-O---I- 71- 0 0 (") O--}/ Þ~D· C-'---O-(\.-l~ Ne1 5 - W c:: I,J 0"") Numher, ~2; .0101 I ¡ï I 1 I-I, : "-..-JL;I 'j 11 1 1 _1'_1-:-'.-' __:J loc. 1 3 ~ ! -- ~-~ --=~~-S , i-"- I 1/4 1/4 1/4 section, ·.TI ¡~ ~-~-~~ . T~lL~Ji=~JOpC1 ¡lµ :c_! *: , ---¡ to~ nshlP. range, merJd Location [ 1 4 = h-¡Y P "0 III \(, ~~ -.L 1~~~ ~.:.l:i ~-"':..:7:ô----T;l Scale ~L,,"""L':'\.J_.J .u -, !ß¡-I~I Mal' L ¡ Altitude . 1 6 ~ i 1\51. 1 '~ '* :_1 0 C E 0 H ~~:~;:~,fent G~;J _ ~~_~ 0 =~ ¿d1Imeu·'. IEo"OPI. map i *; r;;~.~;l Accuracy L ._~l-b_~ Tol'O -Sl!ttlng r 19 = [ L t depreH1on, !t'~iJm. dunes cha'loel '¡,;!, hilltop SIr-to. s....amp. offshore. pe-d!mer.t, hillside. terract'o undw!<!t,r.g. yaHe... upL;;_"~' flat dra-... p ~~-- ~~_m~~___;:,.,¡- Hydrologic !;~1,(j :) f- ()7.C\:~¡ Uni1 (OWDC) L_~ ~ i I ~ I'=. _L¿..:..'"'..L~I~~ Date 01 fllst , ¡ Construction I' 2 1 = 0 J- . D L\ Con1pletlOn' - m.l.lIth day ~sfe r;- 3 ;! A D Site L -- --! anode. drain, ge-.. '(1 /: (Z'*l Jd j<' 1 ., J H -Ø=_M_~~--=--~ ~__ S~~-U-~-~---~ n _Z -:~! obsen mine. oil or, recharge. repress. test. unused. with- waste. destroyed allon. gas d~awal, G heat. I " -.- -lJle of WiJler f 2 ~-I· A - ------- --~~--- ., all cond . BCD H M IN"', R S T U Y Z bottIH'C]. commercl~l. dn.. at"". p~;;~-, fire. -do~~-'~;;~~-;~-'~-~-~-;d-,-c;~-a-'~-I-nd\~'2-,~-~~bi~~~~~--~~k~ltutlon.--unused. desai, other su pply , * : Second" \' Water Use I ' ._~_:l_ < ~ <I)~-,-- Source oj ¡ 29; 'R.¡ * Depth Data !, TertIary Us.: 2~· =1·1 * 1 Depth of; 27: of Wa1er ~ ...:::..:.1.---,----, Hol, --rj UJ._--)~uu_. r;: Docp!h of ¡;-8~ --~~C-S-"? ---1~ j LL·! ! ; , \Vell ; -, ; ¡~.: !* ¡ r; o-~r~ -- - r -I--~ \'.'''1'1 le\,1 ~ -. 1 0" '., 1 1 J ~--_..., -, CD ~ 3 3 0 ! 1<-1 * : Source ~___~_------' ! 3 1 : I......'";; / D Dale r.'easured _... L\_ me-nth da, / ~ i? (--:~2~~ 'r" ear -----_. --- Mrthod of Measurement 13~_c.~ ðlflu\,_ s1ee'. eie-ctrlC callb~ated. o:h~ tape tapE- e!e.:trrt. tapt' C M R v z * G H T ---- ------ C.l' I~;r ,1: Pl..i èllfl.n>: '_""';~Irndoo p'es.-sure. calibrated 9eoph,·si~l. maname1e-r. rep.::Hted logs gage p'~t.lreg.age SIte SI;,I,,' , 37 . 1--- D v x * -- ------~--- --- ------ ø G H R T - - - - --- ----- - -- ---- -- dry. flo.....w.g neJfby, flow,r\9 nearby·, lecf:'nlly f ú...~ing obs1ruC';¡':.,Il. pump,n~ recent!,;. nearby. nearby, forelgr, surfacl?' water pumped pumping recently subna!1ce e1f~ts pumped olhe-r :)....¡3=- Y *. 0.2 6 \ \~ bCj* Source of. Œ' 36· ~ID: *_1 Geohydrologlc Data _~ Measuring POint r'¡¡easuring Poin1 Date 266; - /"! _u_______~__ 35: I * Pump Used _ __-'-~ no 267: * mO!lth day yea, OWNFR IDENTIFICATION (li I R = 1581~ C2::1 CÐ D M ß odd, d"l,,", modify Name: Last Œ~::~:}::),\ .0 I ô,I ILl ,0 Ie :::{::{::{:::i:::::E] Date of . f"i"5"9iiÏ 1\ "J.. / D \ / ; Q r If r;1 Owne rsh I P L...:...:.:..:. V I I 1 I I I \D I ..... L.:.J month d.y y..r 1:1 162;1;'~'" L-~~u~P~----~-~ First L...-i~----'--!...--,- ~ ~ Middle I 1 6 3 : Initial ' ¡ * i OTHER SITE IDENTIFICATION NUMBERS (11 IR= 1890 C!:](A) 0 M G 'dent~1o 101 \ I G Assigner 191: ¡A..k yY)Q, o Assigner r~A',{ ,~¡G.¡ *, arid. delett' mod", [2:!~~J "r-, "7 'h Ident 190 # .J.,,_: 1·-' I I 'I Ne... Card Sam.· R /I. T ,* ; SITE VISIT DATA (11 R=186ß GAD M I~ Date of §I VISit I~ Name of PElSor I / month / 1 88; : .--,-~~~:r:~.l'::':.l::~*-' ~ _..L-.l..~~~P_ d.y acid dl'l("h' year FIELD ~·.AHr-: OLJAlITY MEASUREMEr-..:TS IR=1921*1 I T= I A D (i) M 1*1 Date ~I G / / Geohydro logic Unit 1 95 ;: :* add de1e1p msd,f'r fT'(.-nth r,;;¡¡1 0 0 0 1 0 r;1 Temperature ~ I I I 1 12.J Conductance ~ 0 1 0 1 0 1 9 I 51~ I I '* . : day C 1197 ~ i Degrees , . . ·1 N~·..·.. G.:lrd Same R thrll 19:; µ Mhos /197 0 I Other (STORETI ~ Parameter *1 . ! * I EJ I~ ValUE 11970 ¡ ¡- Other (STORETI f';";;#l Parameter ~ Value 1197 ~ I FOOT NOTES CD Suurce of Oala Codcs r D ø R G A . - ----- "----- -- "'P<HII1IÇ d, ,IIf" ú!/'rlIlPf. 01hpr go~··t otheo- loy"> ! _ glS! ðgf-( C r feµutlEd .. " ~ (~..\. .. ~ '" ... . .~ ;. -~ll Log - ~~~ls River 13-2 0- 4 tt gravel (TXlJ/..UN6- Pt7-v) 4- 14 pea.t 14 - 18 cla.y 78 - 99 hard rocky clay 99 - 106 water streaks in clay 106 - 107 Good water gravel 107 - 127 streaks water, sand, & clay 127 - 160 silt ,sand,water,&clay 160 -190 rocky clay 190 - 20I soft gray clay 201 - 206 dirty sandy silt .206 - 236 heaving silty water & sand 236 - 238 black sand 238 - 260 heaving silty sand & water 260 - 316 rocky Clay Pert orated 96 to 104 at 4 slovs per ft. Perforated 104 tò 127 at 2 slots per ft. Static level 65 ft. Balled _0 gal per min with 4 ft., drawdown Pumped 30 gal. per.min. 12 hrs. Set contractors pump at I30 ft. 7" I b~()~ D-J~;¿(, FfB:16196 NoioRAOE 01$: tIJw 1C,,7l!)IN 2/1/68 R~ To; Standard 011 ot California Western Operations Box 7-839 Anchorage, Alaska Frank Kraxberger Drilling Rt. 2 Soldotna, Alaska 99669 . . .~ -- 4 r.... #2 Unocal Oil & Gas Diy, ~,~ Unocal COrDoratlon PO. Box 190247 Anchoraae, Alaska 99519-0247 Teiephoñe (907) 276-7600 UNOCALŒ~ G. A. Graham District Operations Manager AlaSKa District December 7, 1~88 Mr. C.V. Chatterton, Chairman Alaska Oil and Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Ak. 99501 Dear Mr. Chatterton: '·C=- INJECTION APPLICATION LEWIS RIVER UNIT - WELL 0-1 MAT-SU BOROUGH, ALASKA Union Oil Company of California, DBA UNOCAL, as operator of the Lewis River Uni t, requests tlìat an injection order be issued to authorize conversion of Lewis River Well No. 0-1 from a plugged and abandoned gas well to a Class II dl.sposal well. This well will be used to inject non-hazardous waste fluids generated ouring normal dri~ling, workover and production operations. Currently: Unoc21 operatea gas wells In the Lewis River Area are not being produced at their full potential due to the lack of water disposal facili ties. Approval of Unocal' s application will remove a major impediment to producing idle gas wells and increasing gas production from active wells. The attacned application will demonstrate to the Commission that the proposed disposal operation will not allow the movement of injected fluids into sources of freshwater. Snould you have any questions regarding this application you may contact Roy Roberts or Candace Lockwood at Unocal's Anchorage office. Thank you for your consideration of Unocal's application. Very truly yours, r \~ f f". r~, R i"" (ro- \/ f~ L) t- ~ \¡¡ ~J"'~ ,1- ~ DEC ..- ß 't9ßß , ... _ .."'v; COÍiWfÙSSìOl~ \"k~¡ O'Ù &. O'3S v~~,;c~.·:\ Må~~g~r AnCriQí Q.IJ... ... .-~ /./1 /_7 :;. - ¿ ~7 / -7 L::/ ;' <-.;7 ,( .. .~ '/77 G.A. Graham District Operations -. ~~ LEWIS RIVER UNIT APPLICATION TO TH~ AOGCC FOR UNDERGROUND INJECTION UNION OIL COMPANY OF CALIFORNIA -~~- --~--.--' ~' \ \ i t, Y) 1"" C. t \ \J '~p Co- R~- ~- 1.<'" ') (" ~ ,-,t, ¡\ . C'" Dr::) U ,',I I . SS\O\ì, D t, ",-;0:::'. CG\\\\í\\ \.....i" ...'\r<:, Çi'~ &. '\ "''''\w'{ ð..Ç}13 '~~'ó....,\.,,,, r-J\IJ '~-- --=-~ LEWIS RIVER UNIT INJECTION APPLICATION 20 AAC 25.252(c)(1) Exnioi t No. I is a plat showing the Lewis River Unit, wells wi thin the unit and 1/4 mile radius around the proposed disposal well, 0-1. Al though the proposed injection well is outside of the Lewis River Unit boundaries, ttle 0-1 lease is held by the Lewis River Unit. 20 AAC 25.¿52(c)(L) Union Oil Cornpany of California, dba Unocal, CIRl and OXY USA, INC. are co-owner's in the Lewis River Unit. Unocal is operator of the Unit and the Stëte of AlasKa is the surface owner. Exhibit No. 2 lists the operators and surface owne~ within 1/4 mile radius of the proposed well. 20 AAC 25.252(c)(3) Exlìioi t No. 3 is an affidavit stìowing that the operators and surface owner have been provided with a copy of this application. 20 AAC 25.2~2(c)(4) L,~~ Exhioit No.4 contains geological information for tne Lewis River Unit. 20 AA= 25.252(c)(5) Logs for Well 0-1 nave previously been suomitted to the AOGCC. ~Ie electric log has been included in tnis permit request and lS discussed and referred to in Exhibit 4. (Geological Support Information). 20 AAC 25.252(c)(6) Exnibit No.5 shows present casing detail and wsllbore condition of Well D-1. A new schematic showing current and proposed conoi tion will be sent to the Commission at a later date to replace Exhioi t Î~o. 5. Testing of casing integrity will be in accordance with 20 AAC 25.030(g). 20 AAC 25.252(c)(7) Unucal will oe injecting non-nazardous fluids associated with drilling, production and workover projects. Such f~-1ids may include, out are not limited to: l) Produced \\¿ter 2) O~illing/CJmJletion Fluids 3) E:¡~ipmen: \¡'ashwater Exhi:it No. 6 is an analysis of a representatlve sample of produced \:ater from Lewis River and Exhibit 6a is an analysis of prolJûced water from Pretty CreeK. FluidS will be transported by Vdcuum truck fr~~ various locations to tne injec:tioi) facilities at Lewis River. Exhibit No. ShOWS the composition of tne typical completion fluid proposed for use ouring workover uperations. --- ~~- Lewis River Unit Injection Application Page 2 Tne maximum daily injection should not exceed 500 BWPD, based on operational limi tations of the surface equipment proposed for installation. Tne average daily injection rate is estimated at 75 BWPD, based on the anticipated water production rates of the producing wells. 20 AAC 25.252(c)l8) & 19) UST tests (Exhioit 119) show that the formation pressure gradient of the proposed injection zones (2562'-3918'1.,,10) range from 0.52 - 0.54 psi/ft. in comp2rison to the fracture graaient of 0.822 psi/ft, as determined from a cement squeeze at a depth of 3070' VO. The anticipated maximum surface injection pressure will be approximately 1500 psi. Prior to injection operations a step rate test will be performed to confirm the fracture gradient and establish a maximum injection pressure. Based on a average daily injection rate of 75 BWPO, for fifteen years, the extent of radial invasion is estimated at 275'. Exhibit No. 8 is a calculation showing extent of invasion. 20 AAC 25.252(c)(10) Exhibit No. 4 contains information regarding formation fluids. ~~-7 20 AAC 25.252(c)(11) Under separate cover, Unocal is submitting an application for aquifer exemption for aquifers contained below 2300' in tne Lewis River 0-1 well. 20 AAC 25.2-'2(0) Disposal Well D-l will ae monitored during injection, in accordance with existing regulations of the Alaska Oil and Gas Conservation Commission. Disposal rates and tubing/casing pressures will be recoraed oaily. Unocal, as operator, will submit reports as required under this section. A mecnanical integrity test will be performeo as required by 20 AAC 25.412 prior to injection. 20 AAC 25.252(e) Unocal requests a waiver of botn requirements under this sectlon. of the disposal equipment will not alloy,' pressures to ~xceed minimum yielo strength of the casing-tubing and changes of 200 reading8 occu:c on a frequent basis due to injection practices, reporti~9 impra~tical and a burden to both parties. Limitations 709ò of the psi between thus making 20 AAC 25.252(h) There are no wells \'¡i thin the Lewis River 0-1 Area of Review. Tne nearest well is approximately 3,000' away. EXHIBIT NO. 1 27 34 T15N-R9W T14N-R9W 3 10 -- --~ .---- --------..- -- I I Lb\\TIS RIVER~UNIT I IND EX MAP I 1" =2000' I 28 I I ! 29 ~ MILE RADIUS i I / \ I . ( \ I I I ~ LEWIS R. I D-1 I \ TD 8025' ! r--!~~-l ! I~ I I I=> ~ LEWIS R. C-l I~ TD 6570' I Iw > rr I(f) J ¡ I I r-) ¡~ I ~ LEWIS R. #1 ! i' TD 9480' L - I I -12 L I , :t?-~LEWIS R. 13-2 TD 11,625' 36 1 LEWIS R. B-1 TD 10,319· I I I I EXHIBIT # 1 LOCATION MAP o EXHIBIT NO. 2 EXHIBIT NO.2 - -~~ 20 AAC ~5.402(2) Listed oelow are the operators ana surface owner within one-quarter mile radius of the proposed disposal well: UNOCAL Mr. Jim Eason, Director Division of Oil and Gas State c" Alaské! P.O. Box 107034 Anchorage, Alaska 99510-7034 CIRI 2525 C Street P.O. Box 93330 Anchorage, Ak. 99509-3330 Attn: Steve Planc~on '~. OXY USA, INC. P.O. dOX 12011 Bake~sfield, Ca. 93389 Attn: Wayne Rodges ~,-- EXHIBIT NO. 3 EXHIBIT NO.3 '- '-~ AFFIDAVI1 STATE OF A~gSKA ) )ss Third Juaicial District) Canoace W. Lockwood, being first duly sworn on oatn, oepüses and says: That I am an employee of Union Oil Company of California (UNOCAL). Tnat on tne ·7 t;:Iv day of December, 1988, I caused to De mailed a true and correct copy of this application to the following operators and su:face owners: Mr. Jim Eason, Director Division of Oil and Gas State of Alaska P.O. Box 107034 Anchorage, Alaska 99510-7034 OXY USA, INC. P.O. Box 12011 Bakersfield, Ca. 93389 Attn: Wayne Rodges CIRI 2525 C Stree~ P.O. 80x 93330 Anchorage, ~~. 99509-3330 Attn: StevE Planchon ..... ~ ·~~.1 \-~ ..... I'" t:..,.,. \ ." \' ß n \ 1 . .-1 ' t< r ''\,.J ~~... ..-' ¡;... , " n Ci ,.... C ,,- f.)i'j Ü ~) D t. j _ ;.,-¡\sc\üf\ .",' (,on\\\1 '" t/J\i,-"""! by placing said copy in the United States Mail with pcstage .' <1 nJ¡:.e.~d::i.\d\ à rtmc'nÇ¡'( z.~ð r- r~~ pi. cert~fied at Anchorage, Alaska. /) "- ~-/ ~:{.. ¿<.~ Candace W. LacKwo SUSSCRI3ED AND SWORN to before me tnis '7 f)\ day of Decembe~, 1988 ~-::;:!:"...."" ,1 1/ ¡, . <---7tLi/jé! i{,/ '~L./ [:. v~/)~ Notary'~uQlic in nd for A~;/k://(·rJ7 My Commission Exp res: ~// Y/ð I EXHIBIT NO. 4 -- "- '--~-=7"" Geologic Support Information for Lewis River 0-1 Injection Permit Application Prepared by Roger B. Stickney (December 6, 1988) The following discussion presents geologic evidence to show that utilizing multiple sands in the Lewis River 0-1 well for water disposal will NOT cause contamination of freshwater aquifers. The relative positions of wells in Lewis River Field are shown on the accompanying index map (Exhibit 1). 0-1 is the northernmost well and is located approximately 3,000' northeast of the nearest other well (C-I). Lewis River 0-1 is an excellent candidate to use for water disposal because testing has shown that it does not contain commercial gas and there are several sands suitable for injection which are well-isolated from freshwater aquifers. In the absence of reliable laboratory water analysis data, electric logs provide the means to discriminate between freshwater sands and those that ccntain saltwater. Because the total dissolved solids (TDS) content (salinity) of fresh water is relatively low, it is a poor electrolyte that exhibits high resistivity. Conversely, if the water is more saline, it conducts electricity better and its resistivity is lower. Within the shallowest logged interval at Lewis River Field, high resistivity values recorded on the electric logs indicate that these sands contain fresh water. Focusing attention on Lewis River 0-1 (Exhibit 4.1 -- see pocket), the base of this zone (characterized by resistivities well over 100 ohm-m) occurs at a depth of 1,192' MO where it is under lain by a layer of interbedded siltstone and coal over 70' thick. Below 1,270' MO, resistivities in the porous sands Qenerally do not exceed 25 ohm-m, a stark contrast to the interval mentioned above. The difference between these two dramatically different salinity environments leaves no doubt that the intervening layer of siltstone and coal is a very effective permeability barrier. Using standard log analysis techniques, the equivalent salinity of formation water (in ppm NaCl) can be estimated in two ways. One is the Rwa method and the other is the SP method. Both techniques were utilized here and the results are detailed and explained under Methodology (Exhibit 4.3). These methods Qenerally underestimate the actual salinity of formation fluid. Of the two, it is felt that the Rwa method yields the more reliable results because the SP method requires some assumptions that do not strictly apply to the Beluga Formation. Even with these imperfect assumptions, the salinity values determined with both methods do corroborate each other in showing that the sands below 1,270' MO contain very salty water (cf. Tables 1 and 2). -----. The results of the Rwa method are oresented in Table 1 and also on the log ( Exhibi t 4.1 -- see pocket). They show that the equi valent salinities are generally between 4,600 and 11,000 ppm NaCl. Because the Rwa method often tends to underestimate salinity, the true values are probably higher yet. The key point is that this salinity range is several times greater than the 500 ppm limit for potability under 18 ACC 70.020 which effectively rules out these sands as being reasonably expected to supply a public water system. As explained earlier (it is also evident from the accompanying log - Exhibit 4.1 -- in pocket), a freshwater aquifer over 1,000' thick lies immediately beneath the surface in the Lewis River Field area. Numerous lakes and ponds there show that the water table remains at or near the surface all year long~ Although Lewis River Field is currently remote from even small population centers, fresh water in this aquifer could be easily tapped by shallow wells should the need ever arise. With continuous recharge from precipitation and snow-melt runoff, this supply of fresh water is virtually limitless. Thus, it would be economically impractical to attempt recovery of drinking water from the underlying saltwater sands. Their depth and the high. cost of desalinization would render such an operation economically unfeasible. Water disposal into the deeper saltwater sands would have no affect on potable water quality available at Lewis River Field. Using the mudlog, together with available electric logs and core data, the confining layers were identified and they are depicted in Exhibit 4.1 (the 0-1 log -- in pocket) by shading in the depth track. The main sands targeted for injection in this well occur within the upper half of the Beluga Formation. They are isolated, not only from each other, but the shallowest injectable zone (at 2,562' MO) is isolated from the near-surface freshwater aquifer by over 1,000 cumulative vertical feet of impermeable strata. The specific zones recommended for injection, are indicated below: Planned Injection Zones (MO) Footage Comments 2,562' - 2,596' 34' Carrel. sd 30O' deeper in C-l. 2,850' - 2,900' 50' Carrel. zone absent in C-l. 2,950' - 2,960' 10' Tested wet in 0-1 & absent in C-l. 3,020' - 3,046' 26' Correl. zone very slty in C-l. 3,714' - 3,768' 54' Tested very subcommercial in C-l. 3,873' 3,893' 2O' Tested wet in 0-1 & no gas in C-l. 3,907' - 3,918' 11' Tested wet in 0-1 & no gas in C-l. Total: 205' A correlation section (Exhibit 4.2 -- in pocket) shows the stratigraphic relationship between Lewis River 0-1 and C-l, the nearest well, located 3,000' to the southwest. The top of the Beluga is represented as a horizontal datum and the vertical scale is in hundreds of feet subsea (55). Proposed injection zones in 0-1 are plotted along the left side of the depth track. Test data for both wells is also shown. 2. .- The generalized dipmeter data, which appears on the cross section, attests to significant structural complexity between the two wells. The opposing dips are consistent with the presence of a structural axis between them~ Indications are also strong that each well is cut by a different fault. Although the quality available seismic data is not good~ our latest interpretation shows that Lewis River C-l and 0-1 are situated in separate faul t blocks. Wi th these observations in mind, there are two key points: First, the geologic structure between these wells appears to be much more complicated than the simplistic stratigraphic correlation section (Exhibit 4.2 -- in pocket) portrays. Secondly, the zones targeted for injection in 0-1 are not in fluid communication with sands in C-l that are capable of commercial gas production. There is good evidence to show that the various fine-grained facies within the Beluga Formation are impermeable, even when they are of limited thickness. OSTs were conducted on several sands between 2,868 and 4,980' MD~ Although none were found to contain commercial gas, sands that did test some gas are as little as 40 feet deeper than others that tested no gas. These results demonstrate that in this area, the sand-deficient, mixed lithologies between the tested zones do act as effective confining layers~ STRATIGRAPHY Glacial: The glacial veneer is characterized by a very poorly sorted mixture of pebbles, cobbles, sand and interstitial clay~ Plant debris in various stages of coalification is also prevalent. At shallow depths, these diverse lithologies tend to be extremely unconsolidated and clay layers are generally discontinuous over large areas. This allows fresh surface runoff to percolate downward unobstructed. As a result, the electric log signatures normally ascribed to the glacial cover include very high resistivity and a featureless spontaneous potential curve. Very slow acoustic travel time is also typical of such noncompacted sediments. In Lewis River 0-1, the thickness of glacial veneer is uncertain. The Sterling Formation that often underlies the Glacial is so similar as to be indistinguishable from it. Sterling Fm: The lithologic description of the Glacial can also apply to parts of the Sterling Formation. These two units may even be transitional in places, although a fluvial origin for the Sterling Formation is well-documented (Hayes, 1976) . The resul ting deposits generally include fining-upward sequences of bedload conglomerates overlain by thick and blocky quartz-rich sands which are often capped by point-bar siltstones and mudstones. Coals are common and represent the vegetative cover of abancbned meanders. Lateral continui t y of these lithologies can be quite good in places. These f luv ial sediments have been subjected to effective winnowing and abrasion processes that are together responsible for excellent porosity development. 3. In the Sterling rormation, the resistivity cu~ often shows a blocky character due to the contrast between the generally resistive sandstone beds and the more conductive, finer-grained interbeds. These lithologies are similarly reflected on the spontaneous potential and acoustic curves which often makes bed boundaries very distinctive. Unfortunately, in the Lewis River 0-1 well, this is not the case. Here, noncompaction limits log resolution such that the contact between the Glacial and the Sterling Formation, if logged, is masked. Under these conditions, fresh connate water can easily saturate the extremely porous, shallow strata (above 1,192' MO) creating the high resistivity response and a lack of usable character on the spontaneous potential curve. Although proprietary seismic indicates that the Sterling Formation is represented in the Lewis River 0-1 well, a clear-cut contact with the overlying Glacial is not recognizable from available logs~ Quite possibly it was penetrated above the logged interval. Whether or not this is true, their cumulative thickness is approximately 1,910' and both units undoubtedly contain freshwater sands to a depth of 1,192' MD. A preoccupation with relative thicknesses of Glacial and Sterling Formation is of little importance. The overriding concern is that the shallow, freshwater zone(s), however subdivided, will remain uncontaminated by the proposed injection program and the above evidence clearly shows this to be true. Beluaa Fm: Within the Beluga Formation, sands are thinner and more lenticular than in the overlying units. They tend to be encased in low-permeability siltstones and mudstones as well as being associated with coals of varying thickness. These are the typical interchannel deposits of braided streams from which the Beluga Formation is interpreted to have originated (Hayes, 1976). Thin, low-porosity stringers occur throughout the section which are probably artifacts of diagenetic cementation. At the higher energy levels which are characteristic of braided streams, finer particles do not have the opportunity to settle out of suspension. Consequently, the resulting sediments tend to be poorly sorted. The "dirty" nature of the Beluga Formation, coupled with the occurrence of hard streaks and coals makes the proposed zones an especially favorable target for injection because permeability should be very low in the finer-grained facies. In Lewis River Field, there is also a coarser conglomeratic facies within the Beluga Formation. These beds have lower porosity than the finer-grained interbeds. The degree to which they are cemented controls their effectiveness as permeability barriers. Compared to the overlying Sterling Formation, log responses are usually quite dissimilar. The alternation between thin sandstones, mudstone, hard streaks and coal creates an irregular resistivity response. With the predominance of finer-grained facies, the spontaneous potential is also "ragged" and is frequently of little help in delineating bed boundaries. A "ratty" acoustic log response is usually very characteristic of the BeluQa Formation. This effect is blurred in the Lewis River D-l well, presumably by a combination of noncompaction and possibly transitional lithology at the contact with the Sterling Formation. 4. The entire Beluga '"F"6rmation is approximately 4, 086~thick. All of the sands that will be utilized for injection (except as a last resort) are within its upper half. Below 3,950' MD, within the lower half of the Beluga Formation, multiple sands were tested and some even produced subcommercial gas. However, test rates and especially pressures are well below what could ever be considered commercial even under the most optimistic market conditions. Log analysis indicates that other sands below those that were tested also have very minor gas saturation. Since it would be possible to safely utilize any of these sands for water disoosal without jeopardizing potential gas recovery, it may be prudent to do so in some cas~s. This would help ensure the availability of sufficient cumulative injection interval in the event that some of the proposed target sands fail to take fluid as well as we hope. At the low rates and pressures we intend to use for water disposal, even under the most pessimistic conditions, the radius of injection around the 0-1 wel1bore will be very shallow, even after 15 years, as substantiated by the engineering calculations in Exhibit 8. Tyonek Fm: Although the Tyonek Formation was penetrated by the Lewis River D-l well, it is considerably deeper than any of the proposed injection targets. Thus, its description is not relevant to this application. References: ---~~ Hayes, J. B., et al., 1976 Contrasts Between Braided and Meandering Stream Deposits, Beluga and Sterling Formations (Tertiary), Cook Inlet, Alaska: in Alaska Geological Society Symposium Proceedings, p. JI-J27. Hilchie, D. W., 1978, Applied Openhole Log Interpretation: Douglas W. Hilchie, Inc., Golden, CO. Merkel, R. H., Well Log Formation Evaluation: AAPG Continuing Education Course Note Series #14, 82 p. Regulations, Jan 83, Alaska Administrative Code, Register 84, Title 18, Chapter 70, p. 16.5. Regulations, Apr 86, Alaska Administrative Code, Register 97, Title 20, Chapter 25, p. 31. Schlumberger, 1978, Log Interpretation Charts: Schlumberger Ltd., 83 p. , 1988, Log Interpretation Principles/Applications, 2nd Edition, Schlumberger Educational Services, 198 P. , 1988, Log Interpretation Charts: Schlumberger Educational Services, 150 P. , 1989, Log Interpretation Charts: Schlumberger Educational Services, 150 p. ~. RBS/pg 26640 5. -- -EXHIBIT 4.1 Electric Log for Lewis River D-1 Well (in pocket) .~~~. .~ .~?-~ EXHIBIT 4.2 Correlation Section (in pocket) c_. EXHIBIT 4.3 - Methodology for Calculating Salinity from Log Data Rwa Method: This technique is based on the following relationships: Rwa = Rt/F, where F = O.621¢2.l5 (Humble formula) Rwa Apparent formation fluid resistivity Rt True formation fluid resistivity F FormatiQ~ resistivity factor ø Porosity For a given sand, if Dorosity, formation temoerature (Tfm) and apparent fluid resistivity are known, it is possible to estimate equivalent salinity (in ppm NaCl). It is assumed that NaCl is the dominant salt where specific knowledge of the actual fluid chemistry is unavailable. Resistivity, read from the deep induction curve (Rild), is assumed to be the best approximation of true resistivity of the formation beyond the zone that was invaded by drilling fluids at the time of logging. The formation resistivity factor eliminates the effect of the rock itself from the resistivity measurement so that the resulting value (Rwa) represents only the contained fluid~ Rwa values, when corrected to formation temperature, can be used to es timate salinity with a standard nomograph (Exhibit 4.4; SChlumberger, 1978). A straight line through any value for Rwa (on the right stem) and the corresponding formation temperature (on the left stem) will intersect the equivalent salinity (on the middle stem). Since determination of salinity this· way involves an exponential of porosity (see Humble formula above), a small error in porosity is reflected as a much larger error in the calculated salinity. In Lewis River 0-1, an acoustic log provides the only available formation porosity data above 2,395' MD. In shallow sediments that have never been deeply buried, there is only minimal compaction due to normal overburden stress. Under such conditions, acoustic logs grossly overestimate porosity. Adjustment of these abnormally high porosity values for noncompaction is done empirically and is, at best, rather subjective. Hence, the results must be utilized with utmost caution. Lacking confidence in the porosity data for the zones shallower than 2,395' MO in the 0-1 well, it was felt that calculated salinities would not be valid and are not shown here. ~ <:. ..,.. r f" ~1 \. j \. \<;\., ¡".'" ~ Ik---<> \. ~~ ' . '!i'b~- ~" "0 ':-: _ .- (' - t.; \' D t.. .J V,i\;¡-;\\SS\\,J'Ù p.~~s\.:,,::-··, . - EXHIBIT 4.3 (continued) -' Below 2,395' MD, a neutron-density log was run which provides more reliable porosi ty data since noncompaction effects are much less dramatic with this tool compared to the acoustic device. Therefore, density porosity (Ø'O) was used in the Humble equation. Because salinity is also a function of temperature, Rwa must be first be corrected to formation temperature (Tfm) in order to obtain the corresponding salinity. Formation temperatures were determined as shown below and they are represented on the log (Exhibit 4.1) at the appropriate depths. Estimated Mean Surface Temp (MST): 35° F (for Cook Inlet area) Maximum Recorded Temp (Tmax) from FOC: 135° F ® 8,025' TMD (-7889), i.e., 7,989' BGL where BGL = Below Ground Level Thermal Gradient (TG): TG = (Tmax - MST)/(Depth BGL/IOO) = (135° F - 35° F)/(7,989'/100) = 1.252° F/IOO' It is felt that salinity estimation with this method is most valid, so this technique was used for selected sands below 2,500' MD. The results appear on the log ( Exhibit 4.1 -- see pocket) and also in Table 1 along with the parameters from which they were calculated. Some sands in this well contain small amounts of gas, yet test results show that even the most prospective ones are subcommercial. The presence of even minor gas is emPhasized because it causes Rwa to apoear abnormally high. This must not be ignored because it will result in salinity estimates that are artifically low. SP Method: This is a well-known approach which involves calculation of formation fluid resistivity (Rw) using the spontaneous potential (SP) curve from the electric log. In general terms, in a given sand having even a small amount of permeability, the character of the SP curve will reflect the degree of salinity contrast between the drilling mud and the fluid in the formation. EXHIBIT 4.3 (continued) '.y-,/ Under ideal conditions, using corresponding salinity) can work utilized very cautiously because To get reliable results, a sand following criteria: the SP curve to determine Rw (and the quite well. Most óften, however, it must be several factors can suppress SP development. wi thin the zone of interest should meet the 1) It needs to be sufficiently thick to allow the SP curve to respond to its fullest extent. This maximum excursion of the SP is called static SP or SSP. The minimum thickness required for this to occur is approximately 30 feet. 2) It should also because these developnent. be "clean", lithologies i.e., devoid of mudstone or shale interspersed wi th sand limi t SP 3) The sand should be 100% water-wet since hydrocarbons can also suppress the SP curve to an unpredictable extent. According to the mudlog and the electric log suite, sands of the Beluga Formation in Lewis River 0-1 (between 1,934' and 6,020' MO), contain significant amounts of mudstone. This most certainly limits SP response. Referring to the depths shown in Table 1, most, if not all of those sands fall short of the ideal criteria listed above. Therefore, others with better SP character were chosen for analysis. As was pointed out above, certain sands do have minor, subcommercial gas saturation which also likely contributes to an SP which is less than the ideal SSP. Several references describe how Rw can be calculated from the SP curve and there are often minor disparities between the various recommended techniques. Usually these differences can be ascribed to the way a particular log analyst chooses to correct for less than ideal conditions in the formation he is analyzing. The service company charts used in this analysis are included herewith as Exhibits 3 through 6. The Schlumberger charts were chosen because they allow the user to make some corrections that are frequently ignored by other general purpose charts. They also circumvent other inappropriate assumptions. Table 2 details the raw data and the values used from each chart. -:::-~ 0.. (J) I R (ohm-m) .01 of °C !.02 /Æ 5OTI0 ·Conversion approximated by: kppm 60-i . gIg -±- .03 R - R (T ,+ 6.77 ) . @75°F .04 70-i 20 17500 2- I T2+ 6.71 (Arps) ¡oF 13000 .05 10000 .06 80-1 or 100 80 ~ooo .08 30 R = R (T I + 21.5 ). 0 60 4000 0.1 I~ 90-1 2 I T2 + 21.5 ,C 3000 40 100-1 30 40 20 l2 1000 50 .3 I~ . 60 ~oo 1.4 150.., 400 .5 I~ 300 .6 4 80 3 200 .8 2 +1.0 200 -i. 100 100 12 I~ I 250 -r12O .8 .6 140 .41- 20 1: '~8 3001- .3 160 .2- i6 180 400 -;:- 200 8 I~ +10 220 © Schlumberger 240 + 500...!- 260 120 I .:s: - i· ~ ~~....../ Exhibit 4.4 Gen-9 I '" 5 RESISTIVITY NCJrv\OGRAPH FOR NaCI S~TIONS ~~i1rrr¡i¡.:~~4 SPONTANEOUS POTE> , I -- ~-. . ., -: :,..--4 .~-'-~ -. . II - II :I, 1; ~ ~ ~ B ~ ~ it ~ 3 ~ J ~ ~ --' Jj .J ~ lì iJ .. ii i 0._____ .,.....-' SP Correction Charts (FOR REPRESENTATIVE CASES) Rs ~ 1 1'0t-, ¡-.:::~~ 5~· ,1.o~l___ I I· ,.0~~ I I 1.o~¡""t"..,~~~d·· .. R.n "0.'" '1-.. "" ,oJ o. ~~-......;t-" . o. '{ """':-0:r'>~,,1 o~ "\"'f'.: "'i'-.1.~ '1 ....: .. ~ .. .... . 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RxoIRn (for iriVáded cases); interp6laûng :~t~;~i~~ 11 Exhibit 4.5 SI'O~1A"'r Ol", POTE\'TJAL '----- .- R\veq Determination froil1 EssP (CLEAN FORMATIONS) ... _:~ ~ -~~·::~~.~~:~:~~.~-~~~r.~~'f-S~~~~:·i~·~·.~_::{~.~:_-~:-::::~: . ~, _ _- - . .... ~ " This chart and' ri~;';;C;g;~~h-êalè~laté the equivalent formation water resistivity, Rweq, from the static spontaneous potential, Ess~~ measurement in clean formations. ....' ... . .: , . ' Enter the nomograp}{with E~sp in m V turning through the reservoir temperature in OF or °C to define the " .'. ,Rmrt'Q/R,,~q rat~o.,~rom ~~Îsval~~, p~ss ~hrough the Rmfcq value to define Rwcq. For predo'rnÎmlI1Úy NaCI muds determine Rmfeq as follows: a. If Rm·rat 75°F (24°C) is greater than 0.1 üom, correct Rmfto formation temperaturè .·>é_ .,',.. ":."usingÇh~f,iGe,~:?,,and use. RmfeQ=0.85 Rmf~..: ~.;; ,,_~ ;~c._~.- '._ . .... _. ...~. Ld :~'.'- .;.-........... _.', -,. ".r... -J ~-·:F;~i~!'-&"-Þ. .''';'_ ..,..~'I'r . ..' . . - -. _ - . .,' - .- .1_' ....~. b-:. I.f _R·~r~·~~~_..?~~.E_(~~~C)_i~_.Iess lhan_~O.l ~~"!, ~se Chart .SP-2 19. ~eri~e .a._\!alu~. . '.'~ o~,.,.~~.{~~·~.~! ,~?r,~.~~.i.?~ t~mperat ~:e. '" ," -. ..;_... ·".·(.t ............1·10 ".___.',,",' "..... ',..~ _. _ _ __. _ . _ '._ _~ ~ ->..;- .'. ""-.;- EXAMPLE: SSP is 100 mV at 250°F. ·;·<·:"·:--,·:-.It't.t~:r R~¡~~O.7Òp·m @ 100°F·orO.33 n·m @ 250°F.:·._ ~ . ~: ;.:;' :.~'·::~~~'-~::'rrh~ièfore; R~'f~ = 0.85 x 0.33 = 0.28 n·m @ 250°F. ....~' ~... . R'···· 0 025 n @ 250°F ' '.~":>."'~~;,I·'·'/~~r:~~·:··.?~ wee¡.=: ~_. _. i\,·m ... -~., - - - _.O;:~:.~',:.,,:,._:_ :.... "'1! -~._ ..~':.¡.. . -'.. ~. .' : :.' ;~ -, - - :~. .~ . . . . . . .'... .'. .:... '.' R·· .-', Essp = - Kc10g mr~ . '. .;_.:>~: .. Rw~·: Kc=61 +0.133 T~F .. . . Kc = 65.+ 0.24 T~c - .",." ..; . Rmf~q I R~eq . .3 -~- .4 .6 . . Rmfeq' ." . -. n·m "lO'd· ___A .02 .04 .06 .1 .2 .4 .6 l~ 1..4 ts 10 20 40 60 - 100 .8 2 ell ~ a: -. ell Ë a: .... 4 0 Ë ro - 6 ~ co 8 10 20 CSchlumberger SP-1 8 ExhF~it 4.6 -<Fit.;:-;:.. . ---",~,,* ~~ ~~ ~ ~ ~~ 1.0-1. ~ -.~"" ~' ~ ~. ~ !í!. ~: ~: ~ ~- ~ ~ ~ ~ ~ ~ ""'-: j I .. ~ j ~- ..-' -. L- ~' '" ,J -- - " , » - - -=.s _. ... _ ..iIIi. --.. - ."" .l!. ~: 1· ;:-.- . --.¡ ~- ~ ~-~ I ~" ~ ., T<~. ,.j SPONTANEOUS POTENTIAL .~ ....", -B - Rw versus RWeQ and Formation Temperature jJ ~1~Þ4~Ø~4K~~~~~~~~;'f¡¿-?~~~~~~~···-~:-'"J.;~"~)~~~:~~"~'M~~~'~~~~ .~~ª-P;~i"!iðt~~<;~f~~'~;a;}..':P;.,_t\~v..'~-~Y"i~~~~m~'t.~~,~",·.·~~,~·;f."·,,,,~~i:.~:~1~~ ro:-F"~cr;-z:-:m-)" "'-f<~"""'"".h" _!& ,-~.,-- -¡<'- i:" """oJ }j:t~; '¿''::'~~im\~ ~ :~ ..';- . .Þ.::.~{ "~ý,~",,,,~o'J, ~ . -. ;:t.~ ,,(:. :'fff.:œ;'" -- . I~\! I~ :~i·:- ': ~. .:: .~:~p.~!!.~~S: .'...J,~"~:'.--:~"~:'"' ..¡,(~~~~~~. AJ..~"f!Ir'. 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Th~se~~a:.~ ~~.v.irt,eq·u~~:àI~ñt .;ãt;r}~~~~~vf[y; R~~ f~o;; Ch~r~ SPool L~~ã~~~åI ·~Le~·r~·~·Vi~~ R:~· Th'~~~~~~~:~&: ~ .-."..-.7";. alsobeusedtoconverlR toR' . sal· . d '~-l:.':;': .:. .::'- ~':"'-!' ·'.--::."'r-'-:.~~,~.-;,¡,·..~~~ ,- :.. ..oI.,:"...~...~~-;::-~~~...,.: ....ft..r'.:'!. . _ mf mrcqln memu s. .'..-...~:--. ::.:.---:: c:.JL.·: ;;"'~ _.~.._,.:Þ~·.;.,;".;=-";·,,,:-;¡,-·:-~?"''7..':'·;~;':;':I·-<'~"!L;'~~' ~~'0.y~~.t!!e s.,?Ii~ Elle;; f~(p!ed~~antly ~~~I. waíers._~~:d.~heiì ri~ès Me·~ppr~;.¡;y,~!~!~i::1ãYe':~~;:.t;6hf~!~~.~ ;. '~$~~:~.:~_~~~S{~%~:J~~~.~~~~~.:~~~~~~~~S_I~~~~.~~lgru!i~~~), "!"~~,~~h;d)?~~~ons.~ay ~s~ béÜ~~(tfC?r~~~;ÞI _.' ~.:; "-r_"'-L-N-.~~: "--:'-" .~~.,~-"",,-__-.,I......-""'-........,..,.............~.... ......~ -""-"'"'-j~-- ..!....~ '-.-,c 1"·· ...-, '.-.-::0." ~.1 ~ (continued on next page) 7·.........0/.-! ; ?~~¿~Fif:~l=71rf.~~~"IT~~if.41±1.~:!S~h~f::.:~ê~~~~~¥:f~! .~~~L~..~IT- ls,;;·,s,'-f.r::-.· ,2.........'.., j.....~....,..~~·.k:.~~··r...t"C~ ,I{.;;..,~-"X'...: .-' :....: r-:~~i....~-. .,};..... .:ó~ ..' ~. . ~.""__.;,,¡~¡.1h'.~¥"'~·-;-;~~;.:.:,.1 ~~.;~~·~:>¥~i;~~~~;g.;?}~~¿~;;~%;'Š~.2·-;~:{~}f~~;~~?~~~i:-.;~~~~~~j - - 4.7 Exhibif 9 :W --.., II !I -lI -~ -11 .II -n -n - -a -. .;. -I -I .:J - - II rJ ~ -7i --' ~ -- ~. Table 1 Depth Dens. Equivalent MD SS BGL Tfm Poros. Rt Rwa Salinity (ft) (ft) (ft) (Deg F) (%) (ohm-m) (ohm-m) (ppm NaCl) 2576 2451 2551 66.9 25 12 0.98 6,500 2590 2465 2565 67.1 24 13 0.98 6,500 2853 2728 2828 70.4 20 16 0.81 7,500 2878 2753 2853 70.7 18 14 0.57 11,000 2892 2767 2867 70.9 19 17 0.77 8,000 2955 2830 2930 71.7 22 20 1.24 4,600 3024 2899 2999 72.5 16 25 0.78 7,500 3038 2913 3013 72.7 14 25 0.59 10,050 3482 3356 3456 78.3 17 20 0.71 7,800 3717 3591 3691 81.2 15 21 0.57 9,400 3740 3614 3714 81.4 17 18 0.64 8,500 3758 3632 3732 81.7 19 17 0.77 7,000 3885 3759 3859 83.3 15 25 0.68 7,600 3912 3786 3886 83.6 16 28 0.88 5,800 MD Measured Depth SS Subsea Depth BGL Below Ground Level Tfm Formation Temperature Rt True Resistivity Rwa Apparent Formation Fluid Salinity RBS/pQ 26630 TABLE 2 ~r , Meas Depth (ft) Parameters from Run 3 Rm Rmf Tfm @ Tfm @ Tfm h of DC (ohm-m) (ohm-m) (ft) Hole SP Diam (mv) Rs/Rm (in) SP/ h/dh Rxo/Rm SPcorr SSP (mv) RmfeQ RweQ RweQ Rw RmfeQ/ @ Tfm ® Tfm ® 75°F ® 75°F RwfeQ (ohm-m) (ohm-m) (ohm-m) (ohm-m) EQuiv NaCl ® 75°F (ppm) 2590 67 19 2.10 1.11 24 -10 4.76 14 1. 71 4.76 0.58 -17 1.65 0.94 0.55 0.50 0.50 11,800 2895 71 22 1.99 1.06 30 -10 6.03 16+ 1.88 6.03 0.56 -18 1.75 0.90 0.51 0.49 0.49 12,000 3100 74 23 1.91 1.02 35 -12 21.47 13 2.69 21.47 0.43 -28 2.41 0.87 0.35 0.35 0.35 17,000 3365 77 25 1.85 0.98 38 -10 26.49 12.5 3.04 26.49 0.45 -22 2.00 0.83 0.41 0.42 0.42 14,000 4455 91 33 1.58 0.84 32 -10 9.49 13 2.46 9.49 0.41 -24 2.20 0.71 0.31 0.37 0.37 16,000 Tfm Formation temperature (see log) Rm Mud resistivity (see log header) Rmf Mud filtrate resistivity (see log header) h Bed thickness ( SP Spontaneous potential Rs Shallow formation resistivity Dh Hole diameter Rxo Resistivity of flushed zone (lacking a micro log it is assumed that Rs = Rxo) SPcorr SP correction (see Exhibit 4.5) SSP Static SP (see Exhibit 4.5) RmfeQ EQuivalent mud filtrate resistivity where NaCl is the dominant salt (RmfeQ = 0.85 Rmf since Rmf ® 75° F 0.1 ohm-m; Schlumberger, 1987) RweQ EQuivalent formation water resistivity where NaCl is the dominant salt (see Exhibit 4.6) Rw Resistivity of virgin formation fluid (see Exhibit 4.7) RBS/pg 26680 . .-~. . -, -~._- -...----. .....~_.- ...-~..~._..... --:"'-...... ~~-.. --,---- ,~. "'- ., r -" '.' . I I I I per. manent Datum: GROUND LEVF.:L . Elev.:_1 00 I Etav.: K.8.--1: log Measured From__I:\B 124 Ft. Above Perm. Datum D.F. _.1J Onlling Measured FroN'l_K B.___.________ . G.L. _ 1~ . OW_____---+-fLlli81 ~/18/81 ~l!1K~-- I J ~i~;~.'}.;i¡~~. ~-~.Ütf.1.;- --=1 ~~~~ ~~-- t-~~-L~--.I ~.r~~g..,.~~.__ tl~.~9.__ 6339 ~018 ~___._ [ . t.' ~ (-- J '-. (' , ~ l~ i i '3 h '\ . 2] 9 I) 2 19 r; , I . ...... ----. --+-.-- _.~-. .-------- --- ------.~----+-=------- ------ --.--.-. I~:,.\ !",~ O/¡l_i~~._ _ __-t.,2. 0_ ,(i 3 5~=R~1 j Þ32394 ¡ 1: $1~ 21C)_~.t_.______ '!.! ',:\ng Lnggt'I : -\6] 2]9') , 2 JC) S ; . . -_... ._.... - -r··-------- -..,.----- - .------;)T-.---------- --+---.-. R'fSiu 17]·- ·12.....12- I i~:~_~: ~;0~~~'~-+t~, -;~--=l)~~~\ -, 4 ,,~-î f~_ni) -~ -: - ~~-~ ~ PH_.~..~.L!.·. t~dlo'L: I 8 ~;LJli~l9~Çl:::§~.2.;;~1w:-8T(;-:-"' ~---:-____-_ ..! _s::",!", S~:"£:'~ MilD P.l.1' (1 RC ÇIRC ___~+ ~_ R,.~_.'~~~.Te"'p·135..5 ~67 ~FI 3~14::p 5? cF!:?_~l~ _'i?9_..'.!; .._. .¿.~. '~ .~.::': ~::,~H]? .: ~J '/'~H_f~-~WJ~-+L~:1 ~;:,~ -~ C; .. ~T,u;'f;j(] ~r_,--~ -~5- .-2 J ~~:~: ¡ . 7 . Jätfi-i-F I ~~fTi f-=---:--: ~1Cì;~~jat:;;,}-ï<iY!jfd+f1nö=:- :05(tQ=-~ l02o-º__===-~t --- ~Ll~9ge!..(I~.~~tt~. tHL(L_ ____ LJlíQD_ _ __...Q}J_O_ ____~_.- __n ~.-~.~: ~~(.. ~~IT'. P _...__ 2L. .- --.r-"--~~ ~i!: ~___. F L~lJ--T F J.-.-----, .~~~..J. l~_(~'~_~_ _~ j.'lJ8__..KUiA.lj· ·~H"liliA.. L . J.KENA L+--____j ~'~~dod_~l:__.____,_+.llURGE~ __ . SHEEHAN· ' 1 ~ ..JIAN . W¡InfH\(:-oj By : I)J\ \/T n~()N J nA V ¡ n~()N J r. VFN I nF.1 JTSCI "A~"GE TW" API !I[RIAL ....0 OtherServic~\ t BHC/GR, ¡ FDC/ CNf I¡· CST, RFT . 15N I qW « ~ iJ 1-4 ,! ~ ~j is :'-.:.1 I 1 i ~ , ~ 18 i ; i , I ! I ! ¡1 I I I~ I .xl ' ~ Is i~ '-II~ .--.1 X I ~ Ÿ:1:.r.! 1·--' [-<13' <C' -, ,:L j¡ '~¡ :.~I ~ ~. ¡-! I Z - I. I ~ ¡ g Z Q « :j ð ~ ð ~ v ~ ... FSf. OF SEC COMPANY CITIES SERV1CE, COMPANY J EXHIBIT 4.) . ;.3 {;J ;' ..~ I WELL _______ LEW I S Rl VEB__Q_=-l ----- t FIElD~ LEWIS RIVER ':" '. :,> I COUNTY,_.u MAT-SlJ STATE ALASKA r..- '-1 1rU~~~<.:U ~ ~2 ¡T~" "~~~I"tj¿.~ I - -. -. - -~. -:~ ':.' __",:''';0. - - -'...' . - '. 11:. - - , ...'f,j, .. I v' \ c:, I ~ z . . , (/I: m a: · ....- _.__.~.- ~..~ - - EXHIBIT NO.5. ---~~ v 7 / .-..---: r""1 i I j I 8: I I - ^ I -;- \..1 I i ~ I I I I I ~ I I I I [ f í1 "f'r-, !""'\ r I ,0, ,\.tv ¡ - ;...-....----...r. h·"'..I"\"" ¡. I L. !\~~';:¡ L(-, I ;~Lvl \I ~ for Sq:(d Pertor-alions and ....f !"T-rfi~i0"" q~\~", ~RL.Q : I 0 I I I U II J I ¡...J ...... i V 'í'T .-, '-' ..... ."" r'\ ~ I '" I l' I\-r'tachrv"\ç."";~ ,VlL ¡li¡Iv iL C ':)' Pmpr,~ ; IlliG '-' ,",II... ~ r,r¡ on (\' r,K \ n ~U VI: -, -' \ 0; / I ,..¡ u ~\' J) t\! I 1 (" ~ \ ~ '.- -, J I I I ¡ I ;! -;-1 I ! 5! I I I I I ! r-I o .,..\~ v_ . ) tv I ENT I-'~ , ... v~ i VI ¡:- t\iT ....., '{ I I " I i -oj I I -1 ! -L I ! ¡ i D w ,,.... 'v r~~ DDLE BELUGA Q ¡...J UPPER BELUGA 2 I :v I I jl I ¡ I I I I I I I I I I j I I I I -.J I I 1 1"\ : l 1 r N.... I"", :. rV! L I I r ¡ viTh Pluo A I I I I I I I 1 I I I I I I IlL II II I ~, I~ I I I ! I I I I f'\ L.....),. ABANDONMENT RECORD ... n'''''' (' t ~I ~l ::>UrTo:e vemen ug i.O.C. @ 2ï 45: Cement Retainer @ - 0 C æt "T~"-! I. I. . _ .J...!/ Cement Retainer @ ï (') C @ ,\""021 1..\..1.. vi"! r ' ,.... .. @ ~ement Ketamer Cement Plugs From 2 j 4 :) 6 7 8 3849 5135 33741 2805 PERFORATION RECORD J.. ?8681 ?90n! "' .~..- -- \.. ¡ 2955' 2959¡ \ 2967' 29721.¡ 3070' 3072:j ~,.("'1i -:'J::':/I~ ~~:> ..rn...'-r 1 """"P.2: "'Qi"'jl > ..)~U .,)'.,;~I 3904 3916~ to 7235 íV. V. 20", 94#, H-40 Casing @ 359 Î 3-3/8", 68#, K-55 Casing @ 2395 9-5/81\ 4ï#, N-BO Ccsing @ 5135 CASING DETAIL 23 ~~e!iy Bushing @ 1 30" Driven to 33 t:.A.nIDII nu. ;,J ~ -~ D~'r':""er ,.,. l' \\T ell D-l ¡ p·V~1 ~ ~"e n .L1\../.\.i....... 1\.1\ J. 1 1 .J..U PRESENT CONDITION EXHIBIT NO. 6 2.5 - 12.5 nil'.. 1~O òe 8.:' units EPSW8~5 G:200 óeçrees f EPSW846 }ìO}ì P,!:ì.C!~ 7I I:SW8~é rJa nlE:. IC? 0.£1 ~/l .,. "'P J. \,.. KD(C.CS) !rt9/1 ICP 0.22 m;/l ICP 0.21 IDg/l "'''þ .L .... 8.1 nç/l T"t> .... Im(O.Ol) !rt9/1 ICP }¡1)(0.05) mg/l -1~Þ }{DCO.OS) IÐ;/l IC? 5.S m;/l I:P HD(C.OS) m;!l IC? ;.~ Irq/l IC? C.06 m;/l 1::> Ki)(C.05) rv;/l ICP HD(G.ûS) ng/l rcp HD(Q.OS) JIg/l 8.0 ro;/l IC? KD(O.C5) m;/l rcp 5.2 c;/l ICP HD(O.OS) ro;/l . "'P 1 \.... p:. CORROSIVI'I! ¿e;rees r,!L!MY~B!L!IY ?D.::I\'!':! IC?-25 ELE~h~ SCÀH }'.:J.lŒh~ }J.S~)iIC llill* lORD!' ClL:IUX Ci.DlaUY. CEOY-IID! CO?PEP. 1:.01' )lJ.~~::SI~ YJJiG!J\t 5r ~F.CURI XICrn '=_- PE~S?B8P.O"CS PO:J.SSIID! SI:t}iIUH SILICOH Sl: nR ~~14:; .--------------------------------------------------------------------------------------------------------------- i . EF :rOXIC!7T"INORGÀNICS rJE! rJa EP 3W846 HSn;IC >m(o.o:') ~/l EPSW846 5.0 Y¡¿Y.lJD'.J1D BìJ.iID! 0.14 m;/l EPSW846 100.0 InaY.lIt C!DY.JUY. }iD(O. O~) mg/l EPSW846 1. 0 n:.aXiID'-lro C~:F\CJ)atJ}{ KD(O. 05) rng/l EPSWB46 S. 0 manm'.lrIl LIlD }.1)(O. OS) rIJg/l EPSW&46 5.0 IIoanJD'ùlt . }J1F.~URY KD( 0.001) 1Dg/1 1:PSW846 G. 2 Iü.S.XimUIIl SI:tNIUM 11)(0.01) mg/l EPSW846 1. 0 œnIDun S:LB:R KD(O.CS) mg/l E?SWB46 S.D IãaY.iTD'..lIt lllo\olable bILlts Method F,escH/Un: ts Pe.raIneter !ested ){atrix: Water Lab Sr;pl ID: 1 Chenlab Ref 1: 1373 Inst:u:t: 5pe:: H:.l - . .- - ........................-...........-......--......---.._~_a_____..__.____.____.__________._______._______..-----..-~--_._.---._þ.. L/ - ÀnalYE1' Complete¿ :JUN 21 8B Lbbcrbtcry Supervisor :S!EPHt~ C. EDt I.,hued 11: ~¿;- ~ Send F.epc:- u to: l)miO:H 2) Cllent ~~ : UNO:ÀL Client Àcct : UNOCÀLP P . C . t NONt REC' D teq t Ordered by : CkND! LoctwOOD Client Sanple JD:Lr~~S RIVER PWS~D :UÀ Collected f hrs. Received JUW 10 88 t 13:00 hIs. rreserved with :NOn~ JUN 2 C 1988 C. ,V. LOCK\YOOD À~ÀL!SIS REPOR! l! S~Lr for WorK Order t 7194 Date Report Prlnte¿: JUK 27 BS @ 10:42 ~~ 5633 6 STREET ANCHORAGE. ALASKA 99518 iELEPHONE (907) 562·2343 FEDERAL. TAX ID ~ 92·0040440 CHEA1/C4L & GEOLOGIC4.L L4.BORlJORIES OF AL4SK4, L\7C. '--- - ..,,-~_/ ~ 1k 4 $"4'/-'µ/~ Cí¿J5) o-t!lc ~/5 ~~if /--oJ..cJ .dfi=?£- 5<C;/r/e /Míj~ 4-/- ~J- t7/t/qfC/{ ,:5 0.[' · ct Con~Jv"ltLJq¡~ so...,~. 1{e, ~Q~e Ci1 í6s /73cs 1Y(' IL ;:; "Y/rOj¿,'~!dj t t,,-J of s<?~~ øs-!:r.AA.,{{ -f,)o"" tfDJ h~ ~ /~J Þ-le/I 0--/ t5 ",,-I £ò fV rðd~ ¡:.lþ:Jfif ,~.ç Jßfc. ðd'7Q ¡;, , -j¡ 41 ;:,~II'1 Cf~' . ou 7"/~ l' -Þ!¡fJ rv,;~ If.,- ,/;/...,43' Lú~oGe>() Q"'.,) ~~ ;N-kr,µ.v/ ~ -¡t;.f ~e ¿-~k eo..... e. .co"",, G..J ß¡>e» ;)o/d/>J'j $"J/ ï& ¡11ð;! /;.f0- ,Ç... ...//~ CciNIc,r>1/N'i Ji. I' / I / ,IS ;(lIt..) e-.lq7'vÎ, .~ , --, .-' CHEAfIC4L & GEOLOGICAL L4BOR4TORIES OF A.L45K4., L\~C. 5633 B STREET ANCHORAGE. AL.ASKA 99518 TELEPHONE (907) 562-23~3 FEDERA~ Tt.X ID I; 92-0040440 H:AL!SIS REPORT BY SHœa for ~ork Oràer I 7194 Late teport rrlnteè: JQ~ 27 88 t 10:42 Cllent 5a~ple ID:Lr~1S RIVEh P"SID :UA Cclhcted t hu. ~ecelved JU~ 10 BB t 13:00 h:s. (Ieserved wlth :NONE lnGly£lE Completed :JUH 21 B8 Lab. or.rorr SUPo/~ 'S~EPHE~ c. [DE , , t /'- ~./, / f.e...easea r-)': ., £/-- JI-A-/ Cllent NaBe : UNO:ÀL Cllent Acet : UNO:ALP P.O.' NONE REC·D Req t OIàered ~y : CANDY LO:r.WODD Send Reportl to: l)UNO:AL 2) --..-......................................--......---.-....-.....--......--.--------------------...-----...-----------.-.-.-.-.-.-- Spe::lt.! Instruct: Chernlab Ref t: 1373 Lab SItpl iD: 1 Parameter lested Y..atrÜ: Water F,escl t/Dnits }.{ethod l.llo\òable Littits --------------------------------------------------------------------------------------------------------------- I!"þ "", SODIUY. ~.... S:P.01l"IIID! :IN VUì!DIW Zlh: 2IR:OKIUY. ROt:ih~ WÀTER lHÀL~S!S CRLORIDE SG'..D.7E F.tSIDUt: (~~S) fILTEFJ..tLE FJJ.Dñ1SS (~S C~CC3) 1~Ll:IHI:I (Cë:03) CO}iD0::IV::Y p S=.~~le :. e¡¿~ }:s : 645 Tb';/l 0.81 mg/l HDeO.OS) rog/l HD(O.OS) ~/l HD(O.()S) rog/l KDeO.OS) ~/l f'J a n.I a ~50 ~/l HD U. . G) JDÇ / 1 rJ~~~;," 8.1. ur':t¡; tJt SCPo /1/~ ICP rc:p lCP r c:p ICP 704.. / Q ^1 /"-ð<Y'i 0 -r cis !:ð/~~ß 5~;/S-. ~~4'r~J. ð II&- ~"/~J /H4.£r/á/ re M';'¿" -J ~ /3 ~~..-Jé Q.f~ ~ ¿ / L/I -.¿' / C..¡)/4 ... r ~ 7' "'7 e>L' / / ¡If' ~ /-. ...L ~'-'Y'/ ~ , ...~___~___._____._____._.__......___...._._.._..._.______...____a..____.....____.__._________.__....______.._ '~""-é~- 46 iestE Fe:icrme¿ hl'- ~one De~ected }iì- Ho~ À~lyzed Lí-LeSE Than, GT-G:eater Than I See Special Ins::u:::cns Above II See Së~?le Remarks Åbove 1Jl.. - Una Yë.i labl e " \ - , \ t:.Ar111S11 NU. 0 CI --- CHEJflC4L & GEOLOGIC4L L4BOR4..TORIES OF .4LASK4.. L",rco 5633 B STREET ANCHORAGE. ALASKA 99~,'8 TELEPHONE (907) 562-2343 FEDERAL TAX ID tf 9~-0040440 ANALrSIS REPOR! BY SAY.PLE for Work Order t 7111 Date teport Printed: JU~ 15 88 @ 12:51 Client Sanple ID:PRE::! CREE! - PRODUCED Wl!ER PfiS:D : Collected JU}: 6 88 f hIS . ~eceived J~ 8 88 t 09:45 hrE. Preserved with :HONE Client ~ame : U~O:ÀL Cllent Àcct : UNOCALP P .0 . t Vn.UL teq t Oråered bY : FRED DUTFiLILtR Àn~lYE1E Co~~leted :JUN 1~ 88 Laboratory $~perY1sor :STEPHEN ~;.EDE ~ F,eleased By : ~ L. ~ r Send ~epcrt! to: 1 )UNO:J..L 2)=~ED DUin~ILERoUNO:^L-PRODUCTIOH ..............-.......-......-.....---...---...--.....----.-----.-.....-.--.-.-.-.--......-.----.-.----.-------.-----.-------....-.- Spe:lal ^~:ERHhTE COKTAC!: JOHH BEI!IA 263-767:. lru:truct: Cherolab tef t: 1323 Lab Srnpl ID: 1 Y..atrix: Water ?araroeter !ested F,esul t/Uni tt Method --------------------------------------------------------------------------------------------------------------- EP !OIICI!YO!KORGÀNICS HSDiIC HJ'J ~ C!DY.:m! ŒROJ.GUM L D. D Y.E F. C IE r n/a rJa 0.013 rrç/l 1. 3 JD.~/ 1 11)(0.05) rng/l ND(O.OS) rng/l ND(0.05) rng/l KD(0.002) mg/l ND(O.Ol) rog/l KD(O.OS) rtt~/l 4. 6 ur.:i t s G:200 èieg::ees r ~QH P.H::IŸE EP SWS46 EPSíoìB45 EPSW846 IPSWB46 EPSWô46 EPSW846 EPSWé46 EPS'ioì846 S 11 Hi: ill! SIL~R pH, CO?JWS~VI:I åeç::eer r,r~ÀY.Y~tILITY EF.:::VI:r EPSWS46 EPSioìS46 ~PSWô45 E?S;';S~5 Ser..?l e !\er¿: r.s : Allowable LiI"..i :8 5.0 n.aximuIt 100.0 r..axirn 1 . 0 n.a Y..l1If J.!t S . 0 rua:nnr~ 5.0 maXinr.m 0_2 ItiaY.iID";.l!t 1. 0 ruaz:w.:1Iì S . 0 r¿¿:rnUID 2.5 - 1.2.5 r..in. :40 àe '-~~ 12 7es:s Pe:ic:roed h1)- ~cne Dete::e: IU.- ~:: Àn.e.ly-zeò See Special Ins!!uctionE l~~Ye .. See S~Fle Rema::ks 1bove LT-Less Than, GT-G:eater Than UÀ - ü:':Vë.:: é.~le ..................................--............-.........--..------.....----.....----------.....----........- ~~ , i "'-' CHEAfIC4.L & GEOLOGIC4L L4BOR4.TORIES OF AL4.SK4, L\ìC. '~ ./' l ,.,80......1 OAIE ~ 5633 t STREET ANCHORAGE, ,l..._ASKA 99518 TELEPHONE (907) 562-2343 FEDERAL "7AX ID f 92-0040'-'.0 ANÀL!S:S REPORT t! S~:I for ~crk Order t 7111 Date Report frlnted: JD~ 15 88 f 12:52 Client Sam?le ID:PRr:!! ChErt - PROD0:rD W1:rR PP.'SID : Collected JU}! 6 88 t hr E . Received JO~ 8 88 t 09:45 hrE. Preserved with :~O^~ À~lYE1E Co~plete¿ :JUH 14 88 La~oratory Sup~r?~STEPHE}: C.. ~Dr ./ Released by : ~C,-ç~ / C11ent hame : UN02ÀL Cllent Acct : UNOCALP P.O.t VERBAL Reg f Oròereò ~y FRED DU!~1ILER Sen: Reports to: 1)mmCJ..L 2)fRED DUT~!ILER·UNOCÀL-PRODUC!IOH .-2:.. ~':-~:.~~. J. '~.C" -''''~::--. )f~ -. ....~~~ 1 c ,. ~" ','; - ~!; ~~~~: ---:, ~~...~~? --... .' '. -.I~' ~ ~____"L.~ ~ .... ....~.. - Special ÀL7tRHÀ:E COhi!C!: JOHN tEI!IÅ 263-7672. ...._______....._..__....._.______...._.__....__._.....__......__...~______._______.________________...___________....__....____8___ ImtI\Jet: Cnenlab Ref t: 1323 Lab Sl'IIpl ID: 2 Faral'lleter !eEted Y.~tr::'x: Ì'Ìater Result/U:-'::':E Hlo\lable LiILits He:h:Jd ----------------------------------------------------------------------------------------lr------------:-------- P.ESIDot:(SS) NO}ì-fILTEP.1ELE 1307 m;!l - SqS/~~~ fl1yfé:.-.r/~/ ROD:INt SC1LE AH1L!SlS-S0LIDS nJ~ rJa IGHI!IOK LOSS t 550 òeçIeeE C ~3.0 \ by wgt 1C1D I~SO:~:r ¥~~~RllL HD(O.l) \ zy ~çt I RO!",I AS FE304 W.AGNES I UM SILICON SOiJlUM ALU'v'í I NUM BOR:)N ZlN~ Së.~?le t,er..ë.:}:s: 55 .0 o .5 t O.~9 o . ~ t 0.08 0.07 0.06 --~-ô'--FF .....---...........--....--.....-..-.............-....-........-......---.-........----.........----..-------. Ui.-Dns.'vailë.ble ~ :ests Fe::orrne¿ hT,· ~cne Detecteå hÀ- }iot A~l)~eå See Special In!::uctlc~ Above .. See S~~?~e ~ena:r~ lbove Lí-LeS2 :~nJ Gi-Gr€a:er !~~n '-.....~ -.- -) -, ) .I -- CHEftfIC4L & GEOLOGIC4L L4BOR4TORlES OF ALASK4., 5633 B STREET ANCHORAGE, ALt..SKA 99518 TELEPHONE (907) 562-2343 FEDERAL TAX ID Þ, 92-0040440 HAL ~SIS RtpOR!~! SAY.PLE for ~oÜ C'Ide! t 7111 Date Report Prlnted: JU~ 15 8E f 12:53 Client S4nple ID:PRt!:r CREE! - PRODU:rD WÀ!tR PWSID : Collected Jmì 6 88 . hIlI. Received JUH 8 88 t 09:45 hrE. rIeaerved with :NONt Client ~aBe : UHOCAL Cllent Acet : UNOCALP P .0.1 VERBAL teqt Ordered By : FRED DUTHWIILER ìnalys11 Completed :JUh 14 88 La~oIat~ry Supe:W~STtP2 C;)DE ReleaseCl ly : ~ r ~ Send P,eport. to: l)UHOCH 2 )FUD DU!!fi£::'tF.· UNO~J.L -PRODUCTION .----..----...-.--------------------------------------·------·-------_______..._____.._.._ø_______.______._.___..__._....___....____ Speciel ÀL!ER~A!t CO~!^CI: JOHN BEI!IA 263-7672. Instruct: Ch:nlab Ref t: 1323 Lab Srnpl ID: 3 )(atrix: PiateI Fala~eter !ested Allowable L irn.1 ts Resul t/Un.i tE }.!ethod --------------------------------------------------------------------------------------------------------------- ICP-2S ELEHH1 SCU¡ rJa rJa ICP !L UY.H'UX ND(O.05) ~/l ICP !.P.SEHIC HD(O.OS) ~/l II"'p ... t H.I ffi{ 1.3 Þ;/1 ICP BOP,ON 6.3 re;/l ICP CJ..LCItJ}.{ 120 ~/l ICP CJ. D)I] ill! 0.12 rog/l ICP CHROYJill! lIDCO.OS) I!I;/l ICP COPPER 0.10 m;íl ICP IRO}i f70 nq/l ICP LLJ..D 0.12 w;/l Trp J. v. Y"}' Gh"L SIU}! 5S :¡''' I "'¡ ICP "I - YJ.~:;HESE - . . rog/l ICF }.ŒECffi.Y HD(O.QS) rog/l I!"P tiI Cf.1:t 0.5~ m;/l ICP PEOSPHOF.ODS 0.58 ItI;/l PC':!SSItJ}{ 73 mg/l ""P J."",,, SrLE}i:uy' }iDeO.OS) , . ICP n;g¡ .;, SILICON 15 ' , 1 "P rrt;,.. ..... SIL VIR h'D(O.OS) m; " ICP , .. SDDIUY. l~~O ro;/l ""P l. .... SlF,0hIIUY. O.~S n>;jl 't "'p J. \". 'l:I}i í.C ro;íl T"P J. v\ V}.1i LD I ID! }iD( 0.05) m:;/l I"P v' ZINC 0.72 ro;/l IC? Z n.COHIID! KD(O.05) "JIJ9/1 T,.p J. \". P,OU7Ih1 WJ..TEP. .UV..L ~SIS n/- niB. ' c CRLOF.IDE 2120 ~/l sm.r ).':r . ,.. m;/l ~.u P.!:SID'JL: (:DS) fILTEPJ.tLE 5220 ~/l HP.DRL 55 (as CaC03) 5~2 m::;11 - I .. J.L V. L HI TI (CãC03) l~SO n:>; / 1 ~"\ ) .,- 'o-~ .---- CHEMICa & GEOLOGICAL LABORATORIES OF ALASK4., LVC. ~~, 5632 B STREET ANCH:)RAGE. ALASKA. 99518 TELEPHONE (907) 562-2343 ~~, ,. _. -. .. j).> FEDERAL TAX ID I! 92-0040440 ~......~.~~ ~-::~-~ '-- õ.-- .,,,, Å~ÅL!S1S REPORT !! SAMPLE for ~OI~ Order' 7111 Date Report Printed: JUH 15 88 t 12:54 Client Sample ID:PRtTTI CREEr - PRODU2ED WÀ:ER Pf?SID : Collected JUN 6 88 t h:'$. teceived JUN 8 88 t 09:45 hIs. r:eEerved with :NONE Client Na~ : UNOCÀL Client Àcct : UNOCÀLP P .0,4 VERBlL Req . Ordered By : FRED DU!HWLILER Analysis Conpleted :JU~ 14 BB Laboratory Supe:~~HE~ C. EDE f.eleae f'd ~y : ,>(1./ I .z;.., -:;~ Send Reports to: 1) m¡OCÀL 2)fRED D:1HWIILtt·UNOCÀL-PRODUC7ION .--....................................--....................................-----....---...--......-.....--.....-.................. Special lL!ERNlTt CO~~ÀCT: JOH~ BE!!IÀ 263-7672. Imtruc t: Chemlab Ref t: 1323 Lab S~;::Ù ID: 3 Matrix: \oìater Allowable Parameter !ested F.esul t/tJni ts Method Lin.1ts --------------------------------------------------------------------------------------------------------------- CONDUCiIVITI pH 7690 um.'t¡os/CIt ~.6 unitE Se.;:;:-.:.e ?' . t,ern.:.:"~ : ..-........-..............--................-...................-...........-----.....------.......-.-..-----. "<C__,: 34 :es:s Pe!£or~d h1)- ~one Detected KÀ- ~ot ì~~lyz~à · See Spe:ial l~,;ru::i':n£ !bon .. See Satt?le Remarks lbo;e 17-Less ¡hen. Gí-Gre~te: Than m.-ünayailable EXHIBIT NO. 7 '",--- -..._~ ·,c._ Materië.l Fresn v,late:r Pûtassium Chloride (KCL) Soaium Cnloride (Nacl) XC Polymer (Xanthum8um biopolyme:r) Total - COMPLETION FLUID Percent Dy \~eight 80.B 6.0 12.9 .3 100.0 Pounds Per Sayrel 339 25 55 1 420 EXHIBIT NO.7 '--' Pounds Per Gallon 8.07 .60 1 ""2:1 ........,1... 0.02 10.00 EXHIBIT NO. 8 EXHIBIT NO.8 .- '---- ~,,:;;~ Unocal performed a aetailed analysis of injectaole sands in well 0-1 and their correlations to tne nearest gas producer, well C-l. Based on that analysis, Unocal requests permission to use the following intervals for injection. Zone tf DeDth I·<J and VD Footaoe 1 3,907' - 3,918' II' 2 3,873' - 3,893' 20' -.: 3,714' 3,768' 54' ./ 4 3,020' - 3,046' 26' 5 2,950' - 2,960' 10' 6 2,850' - 2,900' 50' 7 2,562' - 2,596' 34' Justifications for eacn zone '"'~,:::. as follows: a~....... Zones 1 & 2 3,907' - 3,918' / 3,873' - 3,893' '-~ Both these zones have impervious shale barriers above them. Tne lower zone is sealed off on the bottom by mult~ple coals and lo\v-porosity interbeds. Lone 3,907' - 3,918' ¥ías perforated for a OS T during the ini :i21 drilling pnase. TIle zone was shot withou: a cushion, and no gas or water ever reached s~rface. Our ing tne test, surfacE pressure was 0 psi and st10wed no buildUp. Tne final prognosis concluded this zone is not gas productive. Zone 3,873' - 3,893' was never perforô.tej and ooes not appear to correlate to a gas zone in the nearby C-l well. 3,714' - 3.768' ZC;¡= #3 ¡'¡is zone rì2S canf ini~g 2.2y~rs c. ~ least BC' thick above and below it. It was not tested during the original c~illing of the D-1 well but it appears to be correlative to a sana tnê: testec noncommercial in the nearby well C-l. It must be noted that the correlative sand in C-1 (OST #7) flowed only 300 MCFPD of wet gas thrQugn a 3/8" choke at 85 psi tubing pressure. 1iîese numbers represent an extremely wet gas reservoir with a very limited accumulation and trH::refo:-e, tn::: sane W2S squeezed off v,'i tn l50 sacks of cement. ~-~- - ~" ·c.__ By log analysis the po:-osi: y of tiìis sand !ìas been oe~e:-mined to be 189¿. Bé:.seo on injecting 75 8W?0 into tnis 0-1 sand eQuivalent, over a period of 15 years of continuous oêily injection, c ~ tne 75 :I\,'pO rate, the radius of invasion of the injectea f~~ia will De on~y 275'. CAL..CU~A TO!~ - RADIUS OF II~V p,Slor~: R = Radius of Vol~me injected, bbls inv (3.l41) ~ H * p~rosity where: H = injection interval, ft R = inv 410,625 * 5.615 (3.141) (54) (0.18) -oL~ R = 275 ft. in 15 vears ® 75 BWPD. inv 3,020' - 3,046' Zone 114 ~l~S zone has a series of impervious sil:stones cine coals aouve and oelow It y,'êS not testeo in the criºinal C-l w~ll and it does not correlate to gas proouctive sanos in well C-l. ...... l L. any Zone ff 5 & ji6 2,950' - 2.960' / 2,850' - 2,900' ¡.. po:,tion of bo~h these zûnes v¡e::::-e ~es:ed in [;-1 ~'¡itn no gas or water to su:fôce. During the test tne well vIas ~G:enticnally swaGoed without resulting In any gas flow. Neitne:, of these sands ~aYe com~ercial Gas potential in well C-2.. Zone if7 2,562' - 2,596' Tn:s zone was n2t snot in tne original tes:ing of this well. It has over 100' of isolating siltstones and coal di:-ect2.y above ana bel o v,' . No co:-relative san~s ~sa:i~; º2S nave aeen found in well C-l. -----~ EXHIBIT NO. 9 (':. r '(. \\1 t \) ~1("~t -"", ~ ~ 0 ,,_('~~ S G .... \.) \.:) .. '" \) . ,.. ~rl\\~~\ÎJ'\ \' ",.". \.iC\\>\" \.,r. \)\\ 0. {2;).<;;. v~:;.~·, \,\'is'-.;';'' ¡...-(.{..\'\.íJ\(j.~'3 ¡>,\~. r\\'V' '-' OPEN HOLE TEST DATA LEWIS RIVER D-l EXHIBIT #9 '._~ .~ "- ·~ (- ~. --~ ( ---- ,",,--~ \ \~'cll 1~ê~"nC: I-e",'':''s Rive::- D-l D~te c: Test: 9/12/El DST# '.. .. .L.a Fe~:~ G: ~970'-4980' 7ype 0: suns ~seê: :2-1/16" th~ù t.:'S. SPF : 8 { '¡'ocl set @: ~900' ~:'?e of toel ~s~è: F;.T:'s: 7001 ::'-\.:.r1 on: 2::.-i11 pipe H),ë.ro Sp:.-inç \';c. :.cr cus~i 0:1: ~ 0: :ee":.: type fluiè: ~:3a' f'=es~ ~.é. tc:- ~.i.~e :.c~l ~~s cpe~e¿: G2S ~o sur~ace: Ko F!~i¿ to s~~face: No Sur:ace F=ess~=e: 0 ?si : ~¿:=e: !~o Chlc~ic5es: l'~/;' C:~lo::-i6es c: CO:7".? :.;. '\.:~c: l~/;'. .- ~~~e ~=~~ ~~s clcss~: :~~~~21 ~~·¿~~S~2~~= ?=~ss~~e: - . .. .. -.. .. ') _~~~~a~ :~o~~~~ ~~sss~~e: ?~~~: ~~O~~~~ 7=~ss~~e: _ :~~~l.c~~~~:. .i.~.?=e£s~::-e: ~e=~~~ ~~~~~~~ ~_G~~~= ~=css~~e: / -. - . -- / _ _...__ ::~~c=-CS~ë.~~~ ;-=-!2-~~·..:=e: .... - . ·_~C::..~:S r--'- .oJ~ _ "v;2~}: ·_~:::7;S..:-...~~ :. .~-;-~- . . - .... ; ; .- - . - . .---.- ,-.., - .. .., ..... "_" """o.._.o.........\. ~ .'- Page 2 l -. l.. Well 1~ame: Le....·is River D-1 Date of Test: 9/13/81 Perfs @: ~970'-~980' Type of suns used: 2-1/16" th::u t.bg. Tool set @: ~89~' Type of tool used: RTTS: p.y¿ro Spring Tool run on: Drill pipe V;'ater c~shion: # of type fee~: 700' fluid: Fresh water T~me tool was opene¿: 11:29 Gas to surface: No Fluid to surface: No a.m. .- ~ime tool ~as closeå: 1:30 p.~. Initial Dy¿~ostatic ~ressure: 2E96.2 ~ ( ~ I DSTfi· lb- SPF: 8 Surface p~essure: Fla=e: No Chloriães: N/A Chloriães of com? !ni~ial :lo~ing ?=essu=e: 323.3 ?i~al =lowing p=essure: 431.1 ?inal closed in pressure: --- Se=D~¿ ini~i~l =lowing pressDre: --- Final ~y¿rostatic pressure: 2656.2 :. ::.::::71 ~ :-j ~ S : .. . c o psi .¡:'" . "" ~.!.ul.c.: N/A - !', - ~.~::~".~~ ~~:: ::. :~.: :.::;~. ~-'.....;:::':~...- -~':, - . ~ Page 3 ( .I~ -~~- I: \~e 11 !~ 3.TTIe : :'e'¥d s Rive r D-l Date of ':'cst: 9/1~/8l Per:s @: ~675'-4704' Type of suns useà: 2-1/16" thru tbg. Tool set @: ~5Î91 Type of tool \.1seè: RTTS: Hyèro spring TODl ~~ on: Drill pipe hater cushion: # 0: feet: 1000 I type flui¿: fresh water Time tool ~as openeë: 5:00 p.m. G~s to surface: yes :lu~ë to surface:· very little ~i~e tool ~~s closed: 3:45 a.m. .~ ( ~ -DSTI-:,__2,,7 SPF: 8 ( Surface pressure: 0 psi Flare: 61 {l2' ~ëJ:)5::5 pm flare lit Chloriôes: N/A· Chloriães of co~p. fluië: N/A Initial hv¿rcstatic pressure: 25C2_2 Initial flo~i~S pressure: ~56.6 Fi~al flo~ing.?ressure: 500.0 Fi~al closeè in pressure: 761.4 Seco~è i~iti~l ~lo~ing pressure: ~ï8.3 ?i~~l hy¿=cst~tic ==eS5~re: 2373.4 r ,- -"-,0 ":""',..... C . ,--~.~...,._., --. 3~il¿ ~.."". 2.:202..:7i. 0 F.s~ 1: 30 2.. :7.. 1. / ~'si 1:-Ç5 a.r....42 ;:-5i 2:00 a.~. 67 psi :2 :~5 ë..rr~. 9'; ~~... 2:30 2:~5 3:00 a.!:"i. 120 ;:-si - - - . a.Ii.. ~=~ ps:. G.U'. 180 ~si .;,: ~~ ë. .!7.. 205 ':)si 2.: 38 ë... !!'"¡. 23:' psi 2. : 45 ê.. IT.. 260 psi .- I ~.::. ....~: ~. ~ '. ..... . .. .... .- . ".-¡¡:.. ·....""t-..._.... ...: ~ --... Page ~ ( ) ( .' -~ . .-..- - '. -- ....-~- .~. well 1~ë.Jne: Le\""is River D-l Date ot Test: 9/15/81 DST# '~~ 3' Perfs @: 4~4~'-4476' Type of guns used: 4" csg. SPF: 4 ( Tool set @: 3666' Type of tool use¿: RTTS: r.yãro spring Tool run on: D~ill pipe Water cushion: No. # of feet: type fluid: Time tool was opene¿: GëS to surface: Fl~id to surface: 5:30 No No a. rn. Sur:ace pressure: 0 psi Flare: l~o:ìe Chloriåes: l~/Þ. Chloriåes 0: CO~? fluid: N/A ".~:; Time to~l ~GS closed: Initial hy¿rostatic pressure: 2036.4 . ,. n ~ -4- ; a' ~ "i O· "; n c 'D..... &:0 ::0 S'· ..... e . 64. 7 ....J ..1.._ _ ~.L ...._. ~ _ ___ ...._ . :in~l :lo~ing p~essu~e: 99.2 Final closed in pressure: :94.2 Seconè initial :lo~i~g :ress~=e: Final byërcsta~ic ~ressure: 2027.8 CC:-:::le~::'s: 3uilè-..:p ::es~: SI @ 8:30 a.~. 0 ~si 9:30 a.re. 3 psi - " .- - " ,...- . .. - -'.,. :, ..: - _...1 .- .- - - '" ~ Page 5 ( . -. ( "- .' ...... J"'" #.. -,. ~ - -.. ." ~--- +þ -- -- .. .--... --,;.... ,... ~-' .' : Well l;a.me: Le·~·..is River D-l Date of Test: 9/16/81 Ds~fZ-- 4--;- Perfs @: ~327'-~3~7' i "'290'-"'300'; 4315'-4327' SPF: ·4 Type of guns useè: 4" csç. r- Tool set @: -'~/O' &.s,,_..... Type of tool ~seè: RTTS: Hyêro spring Tool run on: Drill pipe Water c~shion: ~o # of fce-=.: type :luië: Time tool WGS opeDeë: 5:10 a.~. Gas to surface: Ve~ sw~:l Fl~id to surf~ce: NODe Surface pressure: 0 psi Flare: None Chloriões: N/A Chloriões of compo flui¿: l~/A '~ T~me to~l ~as closeè: Ini't:'al hv¿ros'tatic Dressure: - ~ 2160.3 Initial flowing pressure: 64.7 TiDal flo~ing pressure: 65.3 F~nal closed iD pressure: 215.6 Secon¿ ini~:'al =lo~ing pressure: --- Final ny¿=cs~atic ~ressure: 2160.3 Co::=: e:-.:' S : 3:.:.il¿ t::) :'e:s't: S·'::: 2-.~i. o ?s:. 2 psi 9 : l 5 ë..:r. . . ~ ": '.c'., i ' ': . ,. . .., ......., .. - --... -- ..~--' . ,. Page 6 ( . ~ ,: ( " -- - ---.....- - -- - .J ~ell Name: Le\o.'is River D-l Date of Test: 9/17/61 DST~ 5'; per!s @:390~'-3916'; 3892'-3897' Type of guns useè: 4" csg. SPF: 4 ,- Tool set @: 3820' '?ype of tool useè: RTTS: Eyè.=o sp::-ing Tool run on: Drill pipe ~ater cushion: No ¥. of feet.: type fluiå: Time tool ~as openeè: 2:35 a.m. Gas to surface: No Fluid to sur~ace: No Sur~~ce pressure: 0 psi' Flare: No Chlo=iëes: N/;" Chlorièes of comp. ~luiè.: N/A Time· tool ~êS close5: :ni~ial hy¿=cs~a~ic pressure: 2091.9 :~iti~l f~o~~n= ~=ess~re: Final flo~inç ?=ess~re: :inal clcse¿ i~ p=essure: 43.:? 43.2 rl- - 0.... ¡ Se=o~¿ initi~: =:~~~~S p~essure: --- ?i~21 ~~·¿~2s~a~~c ==essure: 2079.1 C=~e:'::'s : - ..... i::u:....~c ~"I""'"'. - : 15 2. . ... . 0 ps:.. 6 : .l.;, ê. . ji,i . " '::'si -r~ . .. -... . .. ...."- .j - .....-... .." .* Pôc;e 7 -~ J ..- .~-...",- L- ) .- ~ "'..-- _... -- -~ .. '-t:-_.~.. .""P-. '.__- - . .;-£......,.. .... - ,t;.".¡,I ":7 --........... -_. ...... _;'_:..2..S~.:_.~ _.=._~ '.. .:'::~' . '. . - -. -' .--.....--~~., -- -.-.-----<oi...-- .. ......-..._....:;.. ----~... <. Well };ame: Le\o.'is River D-l Date of ~est: 9/19/81 DST~ 6a ~122'-~1261 i ~Oì7'-~094'· 4062'-40ÓS' Perfs @: ~034' -~054 'i :9S£' 1 -3970' I SPF: T\.'pe of ~uns usee: ~.. ~ ~ ~ csg. 8 :- Tool set @: 38551 Type of tool useë.: Tool ~un on: Drill RTTS: Hydro spring F,ipe \':a ter cus~ion: # of £' eet: 500' type fluiè: fresh water Time tocl ~as opene¿: 8:30 a.~. Gas ~o surface: yes Fl~id to surface: no Su~face pressure: 0 Dsi Flare: very small (2 t)· 10:15 a.m. Chlo~iães: N/A Chlorièes of co~p. fluid: N/A --~ Ti~e t081 ~as clcse¿: 10:45 a.~. Initi~l hyè~cS~ê~ic ~=ess~~e: 20ï3.0 !~itial :lc~ing ?=ess~=e: 30~.4 Final =:o~ing ?=ess~~e: 326.1 ?i~al close¿ in ?=ess~~e: ï38.1 Secc~¿ i~i~iêl ::o~i~; ~=ess~=e: --- :~~êl ~yè~CS~ë~i= ~=ess~=e: :073.0 CC::::7:e::-:'s: : Õ_. .... , . .. .. ". -"-"~.'~:.""""~- ........ --'") ( -) '- ......:.. ;"......: - - .-..~...... - '-'~_ .........""'I'aI.""""-._ .... . ....._.......~:.L.- -'0....._ _~' ~.:::-) (, ) " .._ __, ,. _........."". ......~_9:'''''-..,......- _.0IIt_ "- :-......~ -.;. ."\. ~ ...... -:..' .' -';:.:.. F è ge B __ _ . _ __ _ ........ _..::~.,---..- . - -- --.--- - .. - - _.. ...-- ";;----, .. ! well }~a.me: :..e....·is Ri ver D-1 DSTft .- 6b Date of ~cst: 9/:8/81 Perfs @: S~~e ~s 6a Type 0: guns ~sed: SP!': 8 7001 set @: 3855' Type of tool used: R~~S: Tool run C~: ~=ill pipe P.vëro spring \':ater cus"hion: ~~o ¥. of :eet: type f1uië.: 7ime tool ~GS o?e~eè: 8:00 ?~. Gas :'0 su:::-: ë: ce: ves ';) -r"',Ul"":: ..0 S·'-':--c:. ves see _ """" (,... w__G."-'____ Surface pressure: 0 psi Flare: see att~chments attached Chloriães: see at~achmer.ts Chloriåes of compo flui¿: 2ï7,OOO ppn ~~~. ~i~e ~o~l ~2S c~~sec: 10:05 p.!:'.. In~ti~l hy¿rcstatic pressure: 2079.1 I~it~Gl =lo~i~g p~ess~~e: 86.3 ?in~l :lo~ins pressure: 258.Î ?in~l c:~sec in F~essu=e: 495.Î Secon¿ i~i~~~l flo~ing pre£s~~e: 230.2 ?~~al ~y¿rost2~ic p=essu=e: C~OCK expi~ed ~·~~~I :~D~ ~=ess~re: ~C'Q -...."" C C::::7: '2:-,¡ ~ S : . . .. -.:.~. '-.. ... ¡ .#. . ...--....".." ,.- .. .. ... -...", I. -.-; -.,"""", .. ....~ ~~"'4 .. .. ~·t,~""'~ ".':,. .,........ ,~ ~..j ·_·(.~·"·'IJC_ .' ..-.,. . Page 9 ...~.. : , . -'-'.-.. . ':'est f.'6.B -~ .' -... _ J'~_~.6 _ ....,...'--~--, ",._~'" C:'·'''·, .~.:- :.';\ri(. --+":'<:-;~~-"-""""" : :.-.. ............"-...." ..- ..~;.:... ~- "-- . - _. -- . t- 0_'.. __" .-_ -- ""?'". :.- . .-. -~-.----- -. .-------. --~- ----- Tool open 8:00 p.m. - 0 psi 10:45 p.rr.. - Emall fla::-e ( , to 2 feet) \~ 4:00 a.m. - 6' fla:-e (0 psi) Shut in well ~:oo a. m. - Build up a.rr..- 0 psi a.IT..- 16 psi a.Ii',.- 3S psi ; a . m. - 1.7 psi a.m.- 180 psi 4:00 4:10 4:20 ~:30 6:00 Open tool 6:00 a.m. - ~O· fla::-e 6:05 a.m. - 8 psi :7P-15' fla=e 6:30 a.m. - 0 psi F7P ~:30 p.m. - 0 psi ?~P Well kicked fluid - built to 10 psi a~ 6:00 p.m. 6:10 p.m. - 0 psi F?? Well kicked fluid - built to 30 psi c_ 7:52 p.m. 8:05 p.m. - 2 psi 8:30 p.~. to 2:00 a.~. - 0 psi ?~P 2:00 a.m. - pressu~e ~~il~ing 2:30 a.m. - 20 psi ?T? ~:oo a.~. - 2 Dsi ??? ~ -. ..--- Well s·,.,,·... in - 4: 00 a. In. - 1.:3~ a.:i'.. - 5:00 a.:¡",. - 6: 00 a.~. - buil¿ 'Up 1£5 psi 300 psi 580 ~s~ Operl 'we 2.1 c:. . £" . ;:00 a.~. - E28 psi = ~ 2..:-e w/920 psi - la=çe ï:25 8:CJ a.~. - 5 psi se.~ ló/6~" C:--:ï: 8:10 a.m. 8:20 a.::',. =l~·n· =2.~= #1 5:';S ë..::l. - 9:00 9:5S 2.G:~5 SZ:"..:-:' ':':1 ·..;,=:11 11 : CD 2..::7.. 11:08 2.2:00 2.:00 2:08 ~6 ':)5:" - -. 54 ?S~ c:.. . JU. , -, !-::? í~ - 55 ?si c.. .... - 35D ~:?/~ - ES ?si a.:::. "~-/î ;....-= I -' - ~i :)SJ... --- - ~~:"i::" i..:? "'- .... - ""' - p "'Ie - SO - ì20 ~~.. - ""' ..,. . - 950 p£~ vN"~ ., u::1oë.¿ 2.5 --" C t"\ .....0 Sè-:' lé,/6~" chk 2:2.5 ~/S50 ?si (@ ïGO ;5':' ::.:7'.. ~5 :)5':' - - - O::;.e:1 w,=:12. 2:00 ~. .¡õ.. ::'e:':2.:1 to .",.2. ~e~ - 2:00 ~ - - L~~ ~:?/D 4:00 ~..;¡. 5:00 ?::-.. S:'1~~ we:: _.l 3:30 p.r::. - .:J·":'~~C 1;,? _ .....1_ ........C.... - ---, - :';:>erl \,,'el1 - s e": 5 IS" 6:00 p.~. - S~O c~~' 6::"5 ;:.::-.. (@ 6:25 ?::-:. .s e ": 1 6 I ó ~" c::-- J: 6: 3 0 ~.:Ti. - Ó 2 :; ~ :. ps~ ?r:? ..._~- lO: 00 _ ~C' "": 5,:;0 ?s:.. Y.'e~.L -:'0 U:-.102è \.;ë. te:-) .:::>e~2.:: -- - 3:5 ~:?/~ 86 psi ". - -- " c. . . L.~::-: -'.: ~ ..: :..:..~ , _ ... i.e'· ... _ '" _: -_.<..~- ' . yo" ~ ~ -..,. '. - ....~ ....-~.. .~. ;-) ~-----".,.~.:, -. . ... ~~" ( \ :ê~e -v . . . ..-..........:-\..:.......:1';... _.... _..-- ~ ._.~.....~:..~. .......-..'-":~.. <:- . _.. .L --'---- -. -- ....-"'- -- ~ ."............ - - 't._...;..-.....~.,__- .--- I '. . .--:- .....-- '- . -."- --:--',.- -~ ---. -. .. . ~_._-.-_.... --- ':'est: f6.B co:¡'t. ~~, s~'.,;: we:l =-n :0:30 p_~. - buil¿ ~? -".jf\ -V...Jt./ F·rr~. - 86 580 - E5J psi psi :::30 .... .... !- . "-IL. :::08 a.IT.. ~c; r-- ~ __. _ .'....:.. -.:T'_ .". . l2:38 ê.m. - EJJ ~si C?en ...'e:l :::2:':0 a.m. ...·1 5/ct' c:-Ü: (@ 500 psi ",'€:ll beçan t.o \.:nloa:' \.:ë.:'E::-) Eet. 16/£'';'' chk l:?:.;S a.IT:. - 99 Fsi - 238 !·::F/D (:;o:.e: :l\.:i.è. 176,0:10 ;:,?r..) Sh~t =-~ ~ell 2:00 a.~. - b~i:¿ U? ~:08 a.m. - 5~5 psi ~:15 a.m. wI 5/8" chk - E20 psi C?en "'ell 5E:~ It/£.~II c :- ...:~:. ~:: 0 è. IT.. - 1 0 0 ::'.s i 5:30 a.~.. S~~~ =-n ~ell i~ 6:30 a_~. - ~~~:è _ ì:OO a_~. - 3~5 p~i - 220 ~.,.......-- /....... ..J_: í ..; - 98 psi E:OO è.~. - E95 psi 9:00 a.~. - ~50 p~i C?en "'e::'l 9: 15 ê.. m. "'j 51St. C~;J~ - 9S7 psi (@ 5~O pEi "'ell beçz.n :'0 ¿=-~::::;;.:-c;e ..... z. -: E: :- 10 ==1 9.6 P?S-:~7/008 ~~~) :::00 ~ . ..¡. - 363 !>~:? ID - ::'6 ~si S::~:. ~~ we:l :::00 p.~. - ~~~:è ~~ ~: l : 08 j.. . - 550 psi - : f\r'\ ..., - 270 ?s:i ... Vv . ..,. - : 00 - .,. - -1067 ps:' ~ : 08 - ... . -:200 ;,s:' : "'Î ,..¿ . .1.. . - ':".¿.ll ~C~ - u"" C~-2.:1 v."E::"l 5:C7 ~ - ....:/ o~e 5,··'=," c::...: ~ c::e:.... ::::1:. 5::8 ::;:r~ .. ... . - c..:'s=::ê.=-=~ - :...... - - - --- (.5 ==:-S.3 ~?; :35/000 --~ì ::':-'''.; .:;-:-:' :5/E~1I - -. ,~ -.. , -.. ::: . ..a.. . - c . ~I[" r.~ ~ -: ~~-' í ---- ;.: =? //~ - -' - -,:;.- -.,,...., " " " ..: '"' / '.:'-: c:-.~: S:20 :_~.. - - .\ \ ¿ I . , \./-, '\. ~ : I \,~ /'0' j' " I n..I .... / \.A / \j J C::,se¿ -__r :.:\::15 _ ..... ~ -.,. .' ( ~ )-, ~..: ~ ......... --'-.:""L· _,.,--~_ ..--..p:""'"... .., I... a-. ,;:,,;":..-. ", 't'- -. ~.." ~ .,.r~,,;:.~.;. ';.- :; ~. .., ..:,,¡;;;-- :..-::-.,.,..-;.;..,.. .....,.;.~.... -.......,.... .....~-.... .>. , ~ ·i .~ -...'-"'. '-. Page 11- -(-_~_ '" ~ .-=-.-....-- -.__.....:t'II":T'_ -- ....--..... ...-'~.-- . . \ ~~.J ! \-¡ell 1~ë..r.1e.: Le....·is River D-1 ~ate of Test: 9/~5/81 Dc""'¡: __.Ln 6c .. -.--.. --.. .. . . ':....... --;,.. -.' .--- ~ _. Perfs @:Same as 6a Type of suns used: SPF: 8 7001 se~ @: 39~1 Type of tool used: R~7S: 7001 run on: 2-7/8" t:Jg. Eyèro spring ~ater c~shion: No ~ of feet: type fluid: :i~e to~l ~~s o?e~eè: 3:40 a.m. G~s ~o sur:2~e.: Ye.s :l~iã to su::-:cce: Yes Surface pressu~e: Flare: 3:50 a.m. (very small) Chlo::-iães: N/A Chloriães of comp. fluid: N/A --~: ':'':':71e tc::.l 'v; a S c',....~c.:.:. ..........,-"--. :~i~~21 ~~T¿=o5tstic p=essu~e: 2264.6 1~~~~~1 :lo~i~S ?re£su~e: 258.7 ?i~~l flo~ing p=ess~re: ~ï4.2 ?inGl closed in p=essu~e: 1630.4 Se=o~~ ~~i~i~l =lo~ins p~e~su~e: 495.7 ?':'~a: ~y¿=cs~atic ?=~ss~re: 2143.2 ? .:.::-. 2.l =- :. Oÿ," : ,.c- .. o '~. ~ :~¿ =:~5e¿ ~n: 1301.3 .: c· ::::71 e =-~ :. £: : c.. =. .... - ...., -:'8::1. - "\,~ e::::}" s;¡o:.--=- ~es~ .. .."'"'~~; ... '..'1. .. . _. ..., .. ~~~ ~... . ~..:. ........ ........"T"'. t;o,.:.' . ...... ),- '.'~ ....-;- ~ Page 12 - - -~_. ) \ ~ L - --- ~ -- .. ~- -~~":- .~ ....;..--- '\....~-...- . -=---.._~.. ~-"';";"::..;.;~..... ~ - -:,:.(~..--.- ..... _..... ~-. ....-~4f!'~....~("'--~:: - -)-. .- _. . ""'-.. \. ..' v~e 11 Name : Le\<o' is R i v e r D-1 Date of 7cst: 9/~Bj81 DST# 6D. '''. _._no Perfs @: same as #!6A -O-;-"C_' .___:.__. .,., Type of guns__ used: Tool set @: 3560 I Type of tool Tool run on: Water cushion: No # of feet: type fluid: SPF: 8 'Useè: Drill pipe Time tool was cpene¿: 8-;? p.w. Gas to su~:ace: yes ?luià to su~:ace: no c~r ~ime ~ool ~êS c~ose¿: CO:'7:7,e:::.s: 3"'; ¡.: ,....., ---....... -........ Sur:ace D~essure: r-'--e- \~Os '~~~-? _c._. __ \_.1.__ Ch1o=iòes: N/A Ch lo~ièes cf co:-:'\p. f1 uiè: Njh psi) 10:38 .... .... _. .t... :!rJi'tial n;~è!""cstë.tic p~essure: 2030.1 Initial flo~ing p~ess~~e: ~3.5 :in~l flo~i~g p~essu~e: 651.6 ?inal clcse¿ in ?~essu~e: 651.6 Secc~¿ ini~i21 :lo~ing p=ess~~e: --- ~;-~, ~~~¿rcs~2tic ?=ess~re: ::37.4 , _0 ~:~ 3:::5 è..::'.. - ps:. ~:'::5 .~~~ -- a.r:l. - -;-i Co . "..¡ . - - , .:.": ps:' -... -...... Page 13 {~,~~_n..'^, -.., -~-.-..---......-_. ............;.;..---~ ----- .~"'..'_...../¡~ )"-..s-- 'i..........-<:.. ( "J . __-:,r__ ',"",,~ -- -.__~ .~..... ~"",.""'r ._ .,........._ ... ~:..-_...., (-.~_.JIr....,.. . ~~..' . ..~~) ..' \~ell l:aJne: Le\o,'is River D-l Date of ~est: 9/30/61 . DSTfi 7- -:.::~~:.....-....,.~. Perfs @: 3~51'-3464' '.~-'.':'Ft.'''''__:'U''''':''.i'':'::....-.... Type of guns used: 2-1/16" th:::-u tbg. SPF: 8 Tool set @: 3.356' Type of tool l:se¿: RT'l'S: Tool run on: 2-7/8" the;. Hyèro spring \~ater c~shion: ~ of type feet: 500' fluid: fresh ~ater TiNe teol ~GS openeë: 7:30 a.m. Gas to surface: No Fluid to s~r~ace: No Surface pressure: o psi Flare: Ch1crièes: s~~eço:1D~¿-9.8 ~~= ¿1..., í.JU .-~- Ch loriàes of c c';ï,? f":f.¿'i¿: 390~ ÕÕO --'. ·-~·í Time tool ~as c}cse¿: Initial ~yèrostatic pressure: 1214 :~itial :lo~ins pr~ssüre: ~78 ?i~2.1 flo~ing ?ressure: 651 =i~2.1 close¿ in pressure: 347 Se=c~~ in~~ial :lo~ins ~~ess~~e: --- Fi~al tyèrcstatic ?ressure: 1793 Cc~e:-. ~-s : So..: 2.2:.:":;= - =.; - - '"': _ _..~c.~ :~~~G level 2¿9Jr ~'~J~;- ___, ........... .. r ."!'......:,,-...._. . '-:--" . . -"'~~r.j ~- ~ ~ .~-:-. ä:.-.:I"·~i .. r , ._-:~r- .~.;~, ?açe 14 -; (.. Y, .~~,...~-~".~~ :~ . , .'__'__:".'h -- C· '~", "'~~.'ì-'. -··":""'~·";".r·::", ~,.;.o.-~.._.",.- .__IY""' -.~!~~~-,-~~ ~. \~e11 1~3JT)e: Lev-'is River D-l Date 0: Test: 10/2/81 DS'I'¥.'- B-' Peri's @:2868'-2900" ,:\or..C:'_')OC:O'. ')9 ' , ~__~ ~_~~" 67 -72' Type of guns useè: 4 II csg. SPF: B . - --,.- -.- - Tool set @: 28:5' Type 0: :'001 7001 r~'1 on: eseè: RT'I'S: 2-7/811 tbg P.yèro spr::';¡g \·:ê.ter cushion: !~o ~ .ç: To 0... :eet: type fluiè: Ti~e tool ~~s ope~e¿: 4:40 a.m. Gas to surface: No Fluid to surf~ce: s~a~bed 10.3 DD~ Surface pressure: 0 psi Flare: No Chlor::'èes: 370,000 Chloriòes of Co~? fluiè:370,000 ~::'~e to~l ~2S clcseè: Initial hy¿~ostatic pressure: 1513 :;:i ~ial flc·...,i:-:; p·::-<?5s-.Jre: 217 ?:"r.2.1 =lo;·:ing press:..:re: 43~ ?iDa~ close¿ in ?ress~re: Secc~= ini~i21 :lo~i~g F~ess~~e: ~~~~, hyèrcst2~ic p::-essure: 1513 Co~e:-, -:. s : s·.·:~·:=::' - -, - -. :l::':'::: 2.eve1 :.52.3' ?~~?e= ~Q ~~==el c= ¿i~sel i:1-::; =- C:'7,ê. -:.io:1, s·..·...=.:::~eè. v;·e.:....L. ~~Ell =e~ai~e¿ óea¿. . .... .-....... -p ...-,1.....-: 4. ..~. _! ~--~+." <;::.~".- ..rI. ... \ ... - -.... ~.'!. . ....-........--- Page lS " I -- -~';::":( '1~' - F01"T.ìation ':'ested 6302· 6310 .ç 0'; 5 ~ 0'; 9 ';088 7~40 6545 6542 .... - ~ . ~ -- - .._.....6.:~ .... ......... .:,-.~._-..... Repeat Formation Tests Fluid Recove:--.' None None l;one None NODe None None l~cne '\ ....;.;... --......,It.... ~... (r _~ ___ . or ¡, _ # .,.. ~ ......"!'~--c"It::...,j 6- -ã_... _.. 6 .~_ P~essu~e B~ilëup (Dsi) 4002 1 "r- _1,..i:J :53 118 50 65 240 Q' ",0 #1 --- Unocal Oil & Gas Divisio! Unocai Corporation P.O. Box 190247 Ancnoraae. AlasKa 99519-0247 Telepnon-e (907ì 276-7600 - UNOCAL6¡ December 1, 1988 G. A. Graham District Operations Manager Alaska District Mr. C.V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Ak. 99501 Dear Mr. Chatterton: Application for Freshwater Aquifer Exemption - Lewis River Well D-1 Section 35, T15N, R9W, S.M. Mat-Su Borough, AK. Unocal, in accordance with 20 AAC 25.440, herein submits an "Application for Aquifer Exemption" for Lewis River Well 0-1, for depths below 2,300'. The aquifers contained below 2,300' meet the criteria for exemption as specified in both the State and Federal regulations. (CFR 40 146.4 and 20 AAC 25.440) Unocal respectfully requests that an aquifer exemption be granted for the Lewis River 0-1 Well. Very truly yours, 04 G~/f~~ G.A. Graham District Operations Manager ~./ '~ REQUEST FOR FRESHWATER AQUIFER EXEMPTION UPPER BELUGA FORMATION LEWIS RIVER FIELD submitted by UNOCAL Corporation December 1, 1988 -' -- Geologic Data for Freshwater Aquifer Exemption Upper Beluga Lewis River Field ~ The information below is intended to show that in Lewis River Field (see Exhibi t 1, the index map), sands which correlate wi th the interval below 2,300' MJ in the Lewis River º-:J..=_ well (refer to Exhibit 2, the D-l log) qualify for a Freshwater Aquifer ExemPtion in accordance with 20 ACC 25.440. In the absence of reliable laboratory water analysis data, electric logs provide the means to discriminate between freshwater sands and those that contain sal twater. Because the total dissol ved solids ( TDS) content (salinity) of fresh water is relatively low, it is a poor electrolyte that exhibits high resistivity. Conversely, if the water is more saline, it conducts electricity better and its resistivity is lower~ Within the shallowest logged interval at Lewis River Field, high resistivity values recorded on the electric logs indicate that these sands contain fresh water. Focusing attention on Lewis River D-l (Exhibit 2 -- see pocket), the base of this zone (characterized by resistivities well over 100 ohm-m) occurs at a depth of 1,192' MD where it is under lain by a layer of interbedded siltstone and coal over 70' thick. Below 1,270' MD, resistivities in the porous sands generally do not exceed 25 ohm-m, a stark contrast to the interval mentioned above. The difference between these two dramatically different salinity environments leaves no doubt that the intervening layer of siltstone and coal is a very effective permeability barrier. Using standard log analysis techniques, the equivalent salinity of formation water (in ppm NaCl) can be estimated in two ways. One is the Rwa method and the other is the SP method. Both techniques were utilized here and the results are detailed and explained below under Methodology. These methods generally underestimate the actual salinity of formation fluid. Of the two, it is felt that the Rwa method yields the more reliable results because the SP method requires some assumptions that do not strictly apoly to the Beluga Formation. Even with these imperfect assumptions, the salinity values determined with both methods do corroborate each other in showing that the sands below 1,270' MD contain very salty water (cf. Tables 1 and 2). The results of the Rwa method are oresented in Table 1 and also on the log (Exhibit 2 -- see pocket). They show that the equivalent salinities are generally between 4,600 and 11,000 ppm NaCl. Because the Rwa method often tends to underestimate salinity, the true values are probably higher yet. The key point is that this salini t y range is several times greater than the 500 ppm limit for potability under 18 ACC 70.020 which effectively rules out these sands as being reasonably expected to supply a pUblic water system. ~~ As explained earlier (it is also evident from the accompanying log - Exhibit 2 -- in pocket), a freshwater aquifer over 1,000' thick lies irrrnediately beneath the surface in the Lewis River Field area. Numerous lakes and ponds there show that the water table remains at or near the surface all year long. Although Lewis River Field is currently remote from even small population centers, fresh water in this aquifer could be easily tapped by shallow wells should the need ever arise. Wi th continuous recharge from precipitation and snow-melt runoff, this supply of fresh water is virtually limitless. Thus, it would be economically impractical to attempt recovery of drinking water from the under lying saltwater sands. Their depth and the high· cos t of desalinization would render such an operation economically unfeasible. Methodology for Calculating Salinity from Log Data Rwa Method: This technique is based on the following relationships: Rwa = Rt/F, where F = O.62/Ø2.l5 ·(Humble formula) Rwa Apparent formation fluid resistivity Rt True formation fluid resistivity F Formation resistivity factor )i Porosity For a given sand, if porosity, formation temperature (Tfm) and apparent fluid resistivity are known, it is possible to estimate equivalent salinity (in pprn NaCl). It is assumed that NaCl is the dominant salt where specific knowledge of the actual fluid chemistry is unavailable. Resistivity, read from the deep induction curve (Rild), is assumed to be the best approximation of true resistivity of the formation beyond the zone that was invaded by drilling fluids at the time of logging. The formation resistivity factor eliminates the effect of the rock itself from the resistivity measurement so that the resulting value (Rwa) represents only the contained fluid. Rwa values, when corrected to formation temperature, can be used to estimate salinity with a standard nomograph (Exhibit 3; Schlumberger, 1978). A straight line through any value for Rwa (on the right stem) and the corresponding formation temperature (on the left stem) will intersect the equivalent salinity (on the middle stem). 2. ·.--- Since determination of salinity this way involves an exponential of porosity (see Humble formula above), a small error in porosity is reflected as a much larger error in the calculated salinity. In Lewis River D-1, an acoustic log . = provides the only available formation porosity data above 2~395' MD. In shallow sediments that have never been deeply buried, there is only minimal compaction due to normal overburden stress. Under such conditions, acoustic lOQs grossly overestimate porosity. Adjustment of these abnormally high porosity values for noncompaction is done empirically and is, at best, rather subjective. Hence, the results must be utilized with utmost caution. Lacking confidence in the porosity data for the zones shallower than 2,395' MD in the 0-1 well, it was felt that calculated salinities would not be valid and are not shown here. Below 2,395' MO, a neutron-density log was run which provides more reliable porosity data since noncompaction effects are much less dramatic with this tool compared to the acoustic device. Therefore, density porosity (~) was used in the Humble equation. Because salinity is also a function of temperature, Rwa must be first be corrected to formation temperature (Tfm) in order to obtain the corresponding salinity. Formation temperatures were determined as shown below and they are represented on the log (Exhibit 2) at the appropriate depths. Estimated M~an Surface Temp (MST): 35° F (for Cook Inlet area) Maximum Recorded Temp (Tmax) from FOC: 135° F ® 8025' TMD (-7889), i.e., 7989' BGL where BGL = Below Ground Level Thermal Gradient (TG): TG = (Tmax - MST)/(Oepth BGL/IOO) = (1350 F - 35° F)/(7989'/IOO) = 1.252° F/IOO' It is felt that salinity estimation with this method is most valid, so this technique was used for selected sands below 2,500' MD. The results appear on the log (Exhibit 2 -- see pocket) and also in Table 1 along with the parameters from which they were calculated. Some sands in this well contain small amounts of gas, yet test results show that even the most prospective ones are subcommercial. The presence of even minor gas is emphasized because it causes Rwa to appear abnormally high. This must not be ignored because it will result in salinity estimates that are artifically low. 3. '....../ SP Method: This is a well-known approach which involves calculation of formation fluid resistivity (Rw) using the spontaneous potential (SP) curve from the electric log. In general terms, in a given sand having even a small amount of permeability, the character of the SP curve will reflect the degree of salinity contrast between the drilling mud and the fluid in the formation. Under ideal conditions, using corresponding salinity) can work utilized very cautiously because To get reliable results, a sand following criteria: the SP curve to determine Rw (and the quite well. Most often, however, it must be several factors can suppress SP development. wi thin the zone of interest should meet the 1) It needs to be sufficiently thick to allow the SP curve to respond to its fullest extent. This maximum excursion of the SP is called static SP or SSP. The minimum thickness required for this to occur is approximately 30 feet. 2) It should also because these development. be "clean", lithologies i.e., devoid of mudstone or shale interspersed wi th sand limi t SP 3) The sand should be 100% water-wet since hydrocarbons can also suppress the SP curve to an unpredictable extent. According to the mudlog and the electric log suite, sands of the Beluga Formation in Lewis River 0-1 (between 1,934' and 6,020' MO), contain significant amounts of mudstone. This most certainly limits SP response. Referring to the depths shown in Table 1, most, if not all of those sands fall short of the ideal criteria listed above. Therefore, others with better SP character were chosen for analysis. As was pointed out above, certain sands do have minor, subcommercial gas saturation which also likely contributes to an SP which is less than the ideal SSP. Several references describe how Rw can be calculated from the SP curve and there are often minor disparities between the various recommended techniques. Usually these differences can be ascribed to the way a particular log analyst chooses to correct for less than ideal conditions in the formation he is analyzing. The service company charts used in this analysis are included herewith as Exhibits 3 through 6. The Schlumberger charts were chosen because they allow the user to make some corrections that are frequently ignored by other general purpose charts. They also circumvent other inappropriate assumptions. Table 2 details the raw data and the values used from each chart. 4. -- .........- References: Hayes, J. B., et al., 1976 Contrasts Between Braided and Meandering Stream '-~~, Deposi ts, Beluga and Sterling Formations (Tertiary), Cook Inlet, Alaska: in Alaska Geological Society Symposium Proceedings, p. JI-J27. Hilchie, D. W., 1978, Applied Ooenhole Log Interpretation: Douglas W. Hilchie, Inc., Golden, CO. Merkel, R. H., Well Log Formation Evaluation: AAPG Continuing Education Course Note Series #14, 82 P. Regulations, ADr 86, Alaska Administrative Code, Register 97, Title 20, Chapter 25, p. 31. Schlumberger, 1978, Log Interpretation Charts: Schlumberger Ltd., 83 p. , 1988, Log Interpretation Principles/Applications, 2nd Edition, Schlumberger Educational Services, 198 p. , 1988, Log Interpretation Charts: Schlumberqer Educational Services, 150 p. , 1989, Log Interpretation Charts: Schlumberger Educational Services, 150 p. RBS/pg 26630 5. ~ MILE RADIUS /. "" / " I \ I í \ I' ~ ! \ y LEWIS R.! D-1 34 I \ TD 8025' , r- - t-\- - -~/- ¡ I ~,._ // I I -----~ I -- I , ~ I 1:) .p. LEWIS R. C~ 1 IEJ ! TD 6570' I 1> I- n:: ! I I (/) _ ---l '3: *- ¡~ ¥ LEWIS R. #1 ¡ I TD 9480' I 3 L -- -1 [ -12 i L -~~LEWIS R. 13~2 I TD 11,625' i / I I I ~ LEWIS R. B-1 TD 1 0,3 1 9 . ! I I : I I I I I __~_n~_n _ _ _ _____ n ______n_~ ! : EXHIBIT # 1 r-'_.~---~- i LOCATION MAP 1 36 29 LET~~IS RIVER ~TNIT I INDEX MAP I 1" =2000' 28 ¡-----. T15N-R9W I I T1 : I ! I I I I . I , I I ! H I I , I I I I I 10 27 ¡ - I I I I .1: ."....... EXHIBIT 2 Electric Log for Lewis River D-l Well (in pocket) 5 Gen-9 Exhibit 3 :E .:.: 20 500 R (ohm-m) °C lOI I~ 10 ¡002 ·Conversion approxima fed by: kppm gIg .03 . @ 75°F 1004 (T,+ 6.77 ) 300=['7500 20 R 2= R, Tz+ 6.77 (Arpa) ¡oF 200 13000 .05 \0000 .06 or '\J\J :J- .t .08 -- 5000 30 ( T, + 21.5 ) 60 4000 0.1 I~ R2 = R'Tz +2U5 ; °C 3000 40 30 2000 40 +.2 20 \000 50 f3 I~ \0 8 500 .4 60 400 150., 6 .5 I~ 300 16 4 200 .8 3 200 -L 21\00 1'00 1 Ì I~ 50 I: 250 -t-120 .8 40 .6 30 At 20 I~ I~~ 300 -L .3 .2 ...r e I~ 400-Fc-vV © Schlumberger -r10 RESISTIVITY N07V\OGRAPH FOR NoCI SOrdTIONS -~~i1~~~k~¿q Exhibit 4 11 J.·=1 I I ~.5 Am -; '2' :::.: _ .'~." :.. . 0.8 .~. ~1'llit¡~·: :~If ~---.. . -0': -~.:' . . .-0-':.. - - ',,' - ".. ~!-~: :>.~:"~:~h,:!:.:?,::~~ ,..' ¡ -:;::_o~_;:'i' -,~.j,...~:."~::.~,';"": '~' 0.2 . ',' ¡¡I --:'.':~~~: 1~1'\1irii1..~:f;.;:~~;~.~j~~~T~i~~it~f:~: I i I ':1~}8 .~ - ...... . -.. ~ - ... ~-- ~ ~ Ij~ll¡~~¡~_;;t~;~: :' . ~0:t iN;~i ..__.............._._. _, 0.2 .. -~. 0.2 -.- --i~! -- 0.2 0.2 I ~:-C·~~¥{i1,:~:.;;·,~;. 500 ;~71;;3 !, ¡':' ::{. : _500 ~>~: r '.. '}';".:' .. .,'. _. ." '., A,iA", _ ..~ ..... I I I A.JR... - 200 ,- I I A.JR... . -~.; . :.·.~.~~:--.:;·~4~:··,..':..-;'4~~:.-::"i£.~·;:1 -...=.-:-~~~: .:_: :~...- ._"".aofIIIA........t ~....,_ .."'~............. .. ""_a.- ;.--..-.... ~.: ~.¿. _ ~: 4. Go "'ert icaJly :úp to curVe for appròpriate· R/Rm ··(for· IÌQ invasion) or _.RJL~·· (for invaded èases); interpolatirig"~~~i~ý~:" SP Correction Charts (FOR REPRESENTATIVE CASES) '''----, - ì SPONTANEOUS POTENTIAL ~ _, ,. ..j if ~ ~ ~ ïì II Ii 1! 11 ~ ~ ¡¡ .-Å ii .-J ~ ] i] -~ ~ !j ïJ ~ ~ .:1. .11 :1 :1 .. '1 .. -1 -~""~' i SI'O'\:T.\ '\:LOl", POTl"TI '\L "-~ . .. : ~~~.~;.~~~.~}~:~:~;:.~~;~~.;~-;r~ ::.\~.".',;:~: f::,:-,··.~ . ~ . ' _" -=_ _. .. _ ~ . This chart and n()J;;~g¡'aph ·calculate the equivalent formation water resistivity, Rwcq, from the static spontaneous potential, Essp', measurement in clean formations. Enter the nomograph with Essp in mY turning through the reservoir temperature in of or °C to define the RmrC4/Rwrq ratio..~rom t~~syal~e, pass through the Rmrrq value to define R"rq. For predominaniIy NaCl muds determine RmfrQ as follows: a. If Rmr àt 75°F (24°C) is greater than 0.1 n"m, correct R~fto formation temperature '. _. using Chå¡'~,Gen~?;,(lt:1.d u~~ R~rrq~0.85 Rmr..~ ,.._.__ :_._ _. ._ b. -I f. R~·F"~~i~(oX(24°C) ..is-lèss than .0.1 n·~;·use Ch·a.rt. SP-2 to'derive ·a ,;a"lue . "..~f)~.~·rt~:a~J~!!TI!;~.i~~ temperature. .' _ . ........ 1'0 .-.~' " ).....,.._ ."' _ "...... ~ . EXAMPLE: SSP is 1.0.0 mY at 25D°F. . .:.':- ·~::,~?~~~~~r R~~'~ Ó}.on·m. @ IDDoF or .0.33 n"m @ 2Sp°F. .:: . ..:',-:__:~~", Therefore, Rmrtq = 0.85 x 0.33 = 0.28 n·m @ 25D°F. Rwc~".::: .0.025 O·m @ 250°F. - Rweq Determination from EssP (CLEAN FORMATIONS) Kc = 61 + 0.133 TCF ". ",,'. Kc = 65 + .0.24 Tec . . Rmfeq I Rweq .3 ~ , 6 j: .... I: t i40 60 100 .4 .6 R~feq n·m .8 .:101 + .02 +.04 f·06 2 Q ~ ff (\) Ë a: '- 4 0 Ë ro 6 - ~ ro 8 10 .1 .2 .4 .6 2 4 20 C SChlumberger SP-1 8 2.0 Exhibit 5 ~~ ~ ~ ~ ~ .',. ~: -q ~> ~ ~ ~ ~: E: ~: ~: ~ ~ ~ E¿ ~ ~ ~ î ~ . ~- f g- i ~- ~- ~ ~:¡ - ~ ...:.. - .-~- - ... .%. ~ . ~: .:. 2__ --I ~- "'jJ .-= - - __I ~ - 1 "'1 7g- ,tj .:- ~- r SPONTANEOUS POTENTIAL 71A I -71 R, versus R,,qand Formation Temperature Vr English fIX 001 '�.005 i r .01 0') L7 AL IS .005 01 02 - -t--.03 0 5 0.1 0.2 0.3 a 0.5 -!r WI.0 2 3 4 5 Ft: o• r R z M) These charts convert R from zk;-F�:57 L Ckiiri SPrI to actual water resisti%itv, R,,,.- They may _equivalent water- r6istiNrity, -- also used to convert R,,'fto R,�r�in saline muds'!:!r7Z—n�-' ";.Use the solid lines for predominantly NaCl waters. The dashed lines are approximat'e'fSr!'av'erage". fresh forma- - - d. - . M tloq waters (where effectsiot salts other ti� NaCI become significant). The dashed portions may also tieused f6r (continued on nett page) K. pt'. 'P5 -j6-.L-- Z".. v4V-0 A M 'SP-2 -A. =tt of MI V z 7e - -. I 9 Exhibit 6 - ·-~__r'" Table 1 Depth Dens. Equivalent MD SS BGL Tfm Poros. Rt Rwa Salinity (ft) (ft) (ft) (Deg F) (%) (ohm-m) (ohm-m) (ppm NaCl) 2576 2451 2551 66.9 25 12 0.98 6,500 2590 2465 2565 67.1 24 13 0.98 6,500 2853 2728 2828 70.4 20 16 0.81 7,500 2878 2753 2853 70.7 18 14 0.57 11,000 2892 2767 2867 70.9 19 17 0.77 8,000 2955 2830 2930 71.7 22 20 1.24 4,600 3024 2899 2999 72.5 16 25 0.78 7,500 3038 2913 3013 72.7 14 25 0.59 10,050 3482 3356 3456 78.3 17 20 0.71 7,800 3717 3591 3691 81.2 15 21 0.57 9,400 3740 3614 3714 81.4 17 18 0.64 8,500 3758 3632 3732 81.7 19 17 0.77 7,000 3885 3759 3859 83.3 15 25 0.68 7,600 3912 3786 3886 83.6 16 28 0.88 5,800 MD Measured Depth 5S Subsea Depth BGL Below Ground Level Tfm Formation Temperature Rt True Resistivity Rwa Apparent Formation Fluid Salinity RBS/pg . . 26630 c( Meas" Depth (ft) Parameters from Run 3 Rm Rmf Tfm @ Tfm @ Tfm h of 0C (ohm-m) (ohm-m) (ft) SP (mv) Rs/Rm 2590 67 19 2895 71 22 3100 74 23 3365 77 25 4455 91 33 Tfm Rm Rmf h SP Rs Dh Rxo SPcorr SSP Rmfeq Rweq Rw RBS/pg 26680 2.10 1.11 24 -10 4.76 1.99 1.06 30 -10 6.03 1.91 1.02 35 -12 21.47 1.85 0.98 38 -10 26.49 1.58 0.84 32 -10 9.49 ,~ TABLE 2 ( Equiv Hole Rmfeq Rweq Rweq Rw NaCl Diam SPI SSP Rmfeql @ Tfm ® Tfm ® 75°F ® 75°F ® 75°F (in) h/dh Rxo/Rm SPcorr (mv) Rwfeq (ohm-m) (ohm-m) (ohm-m) (ohm-m) (ppm) . --~~> 14 (.:~71·'4. 76 0.58 -17 1.65 0.94 0.55 0.50 0.50 11,800 '-..R. 16+ 1.88 6.03 0.56 -18 1.75 0.90 0.51 0.49 0.49 12,000 13 2.69 21.47 0.43 -28 2.41 0.87 0.35 0.35 0.35 17 , 000 12.5 3.04 26.49 0.45 -22 2.00 0.83 0.41 0.42 0.42 14,000 13 2.46 9.49 0.41 -24 2.20 0.71 0.31 0.37 0.37 16,000 Formation temperature (see log) Mud resistivity (see log header) Mud filtrate resistivity (see log header) Bed thickness Spontaneous potential Shallow formation resistivity Hole diameter Resistivity of flushed zone (lacking a microlog it is assumed that Rs = Rxo) SP correction (see Exhibit 4.5) Static SP (see Exhibit 4.5) Equivalent mud filtrate resistivity where NaCl is the dominant salt (Rmfeq = 0.85 Rmf since Rmf ® 75° F 0.1 ohm-m; Schlumberger, 1987) Equivalent formation water resistivity where NaCl is the dominant salt (see Exhibit 4.6) Resistivity of virgin formation fluid (see Exhibit 4.7) \ , ¡ I I I . : I ! ¡ ¡ II ¡ ~ I' d· I I ,9 I ~ i~1 ¡~ ¡~ =I~I !~ _1,1 "( I:::! : :~í ¡ ~ ~! ~ ¡ ,;: ,_~tl I, ~ .,.~. ;¿ I.~ I __ I I ~ 1 . 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