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AEO 016
N Colombie, Jody J (DOA) From: Bob Britch <bbritch@bluecrestenergy.com> Sent: Tuesday, September 09, 2014 10:06 AM To: Colombie, Jody J (DOA); Stephen Hennigan; Steve Massey; Larry Burgess Subject: Aquifer exemption Jody In response to our phone conversation several minutes ago, our letter from Steve Massey dated September 2, 2014 was intended only to keep AOGCC informed in BlueCrest's progress in obtaining an Aquifer Exemption from the EPA. We did not intend to have this submitted as an application to the AOGCC, and we request that the document be withdrawn from consideration as an application to AOGCC for an aquifer exemption. Sincerely Bob Britch 754-9557 11 IluCYe s t Energy Steve Massey Vice President - Alaska BlueCrest Alaska Operating LLC 3301 "C" Street, Suite 202 Anchorage, AK 99503 United States of America (907) 754-9550 September 02, 2014 C Ms,Kathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 RE: Alaska Request for Aquifer Exemption related to.. EPA Region 10 Submittal for Aquifer Exemption Request for Class I Disposal Well(s) Request for Aquifer Exemption by BlueCrest Alaska Operating LLC FOR Proposed Class I Injection Well(s) Application— Cosmopolitan Field — Hansen Pad Kenai Peninsula Borough and Cook Inlet Alaska Dear Ms. Foerster, BlueCrest Alaska Operating LLC (BlueCrest) has applied to the EPA for an aquifer exemption to construct Class I disposal wells for the Cosmopolitan Field, Hansen Pad. We applied for the exemption to EPA Region X per their instructions, but realize we still need to comply with Alaska Admin Code including the following among others: 20 AAC 25.440. Freshwater aquifer exemption 20 AAC 25.450. Underground injection control variances 20 AAC 25.460. Area injection orders In summary from the AOGCC, "BlueCrest Alaska Operating LLC (BlueCrest) hereby requests an Aquifer Exemption to allow BlueCrest to construct a Class I disposal well(s) and then inject used drilling mud, cuttings and miscellaneous fluids during drilling and production as long as the well meets ALL technical criteria. Our specific request is to use the Tyonek and Hemlock formations as the zones for injection. The depth requested is from ±3,000 feet TVD to ±6500' feet TVD. Supporting information is attached. In addition, a "no USDW" determination is requested from 6500' and deeper." BlueCrest Alaska Operating UC Page - 2 9/3/2014 BlueCrest does realize that as the project progresses, additional information will be provided to the AOGCC for determining AIO's, etc. If there are any questions and/or any additional information desired, please contact me at the above number or Bob Britch at (907) 240-5830 or Stephen Hennigan at 337-849-5345. Sincerely. BlueCrest Alaska Operating LLC Steve Massey- VP Alaska Enclosures: EPA Class I Aquifer Exemption Application Related Attachments fo Application Cc Chris D Wallace — AOGCC Stephen F Davies — AOGCC Guy Schwartz — AOGCC Dave Roby — AOGCC John M. Martineck — BlueCrest Alaska Operating LLC wo attachments Jack Eells — BlueCrest Alaska Operating LLC wo attachments Larry Burgess — BlueCrest Alaska Operating LLC wo attachments Stephen Hennigan — Petroleum Engineers for BlueCrest Alaska Operating LLC Bob Britch — BlueCrest Alaska Operating LLC rM jle\..BlueCrest Alaska Operating LLC 3301 "C" Street, Suite 202 1 u e C` est Anchorage, AK 99503 EnergyUnited States ofAmerica (907) 223-6358 Steve Massey Vice Presider t - Alaska August 13, 2014 Edward Kowalski, Director USEPA REGION 10 Mail Code: OCE -184 1200 Sixth Avenue Suite 900 Seattle, WA 98101 RE: Request for Aquifer Exemption by BlueCrest Alaska Operating LLC FOR Proposed Class I Injection Well(s) Application— Cosmopolitan Field -- Hansen Pad Kenai Peninsula Borough and Cook Inlet Alaska Dear Mr. Kowalski, BlueCrest Alaska Operating LLC (BlueCrest) hereby requests an Aquifer Exemption to allow BlueCrest to construct a Class I disposal well(s) and then inject used drilling mud, cuttings and miscellaneous fluids during drilling and production as long as the well meets ALL technical criteria. Our specific request is to use the Tyonek and Hemlock formations as the zones for injection. The depth requested is from ±3,000 feet TVD io t6500' feet TVD. Supporting information is attached. In addition, a "no USDW' determination is requested from 6500' and deeper. Back up data is attached as are the AE data entry forms. If there are any questions and/or any additional information desired, please contact me at the above number or Bob Britch at (907) 240-5830 or Stephen Hennigan at 337-849-5345. Sincerely, BlueCre Alaska Ope ng LLC Steve ssey- VP Alaska Enclosures: Class I Aquifer Exemption Application Related Attachments fo Application Cc Thor Cutler USEPA REGION 10 Mall Code: OCE -082 1200 Sixth Avenue Seattle, WA 98101 John M. Martineck— BlueCrest Alaska Operating LLC Jack Eells — BlueCrest Alaska Operating LLC Larry Burgess — BlueCrest Alaska Operating LLC Stephen Hennigan — Petroleum Engineers for BlueCrest Alaska Operating LLC Bob Britch — BlueCrest Alaska Operating LLC L- AO\M.. BlueCrest Alaska Operating LLC r 3302 "C' Street, Suite 202 1 ue est Anchorage, AK 99503 EnergyUnited States ofAmerica (907) 223-6358 Steve Massey Vice President - Alaska August 13, 2014 Edward Kowalski, Director USEPA REGION 10 Mail Code: OCE -184 1200 Sixth Avenue Suite 900 Seattle, WA 98101 RE: Request for Aquifer Exemption by BlueCrest Alaska Operating LLC FOR Proposed Class I Injection Well(s) Application— Cosmopolitan Field — Hansen Pad Kenai Peninsula Borough and Cook Inlet Alaska Dear Mr, Kowalski, BlueCrest Alaska Operating LLC (BlueCrest) hereby requests an Aquifer Exemption to allow BlueCrest to construct a Class I disposal well(s) and then inject used drilling mud, cuttings and miscellaneous fluids during drilling and production as long as the well meets ALL technical criteria. Our specific request is to use the Tyonek and Hemlock formations as the zones for injection. The depth requested is from ±3,000 feet TVD io ±6500' feet TVD. Supporting information is attached. In addition, a "no USDW" determination is requested from 6500' and deeper. Back up data is attached as If there are any questions and/or any additional inforr..J3 (Domestic Only; Provided) Bob Britch at (907) 240-5830 or Stephen Hennigan a- � For delivery r • our • t �♦} Sincerely, Ln �- ru . ru Postage $ $3.50sn n.1 Certified Fee $3.30 T 0 ,r C3 Return Receipt Fee f/ © (Endorsement Required) $2.70O �! BlueCre Alaska Ope ReslrledaeriveryFee ♦-J..«.n.wnM QONI{YGYn ws1 k An Steve assey- VP AI DER: , Enclosures: Class ■ Complete items 1, 2, and 3. Also complete item 4 if Restricted Delivery Is desired. Relate Print your name and address on the reverse Mail Code: OCE -184 so that we can return the card to you. 1200 Sixth Avenue, Suite goo ■ Attach this card to the back of the mailplece, Cc Thor Cutler or on the front if space permits. USEPA REG 1. Article Addressed to: 1200 Sixth A Seattle, WA! AA IF. nrard Kowalski, Director A. Signatu X ❑ Agent '3 Addre,, Received by (Printed Name _ t I C. Date of Delit D. Is delivery address dif#ererrt from item 1? ❑ Yes If YES, enter delivery address below: ❑ No �. 05rnce We L7 Certified Mail 0 Exprm Mail C3 R"Ist6red © Return Receipt for Memhandlse O insured Mail 0 C.O.D. 4. Restricted Delivery? pft fisej Z. ArtlVe Number (rr&Werfromservice IaW) 71112 3460 0002 1225 1576 PS Form 3811, February 2004 Domestic Return Receipt iozsas-azaw-ysaa • U.S, EPA, Region 10 John M. Mar Mail Code: OCE -184 Larry Burge,. Jack E - 1200 Sixth Avenue, Suite goo Stephen Her - Seattle, WA98101 Bob Britch — A. Signatu X ❑ Agent '3 Addre,, Received by (Printed Name _ t I C. Date of Delit D. Is delivery address dif#ererrt from item 1? ❑ Yes If YES, enter delivery address below: ❑ No �. 05rnce We L7 Certified Mail 0 Exprm Mail C3 R"Ist6red © Return Receipt for Memhandlse O insured Mail 0 C.O.D. 4. Restricted Delivery? pft fisej Z. ArtlVe Number (rr&Werfromservice IaW) 71112 3460 0002 1225 1576 PS Form 3811, February 2004 Domestic Return Receipt iozsas-azaw-ysaa • 2aa OW 1 and DW 2 Summary Table 4 Corrected.xlsx Table 4 (Corrected): Area Summary This "group" of similar tables, summarizes the ENTIRE potential wellbore for EACH of the disposal areas. For each disposal well there is a NAD 27 table and a NAD 83 table. The NAD 83 wellbore location data is "calculated" from the NAD 27 data using an in-house algorithm so there may be some slight differences if EPA verifies the data with an in-house program. The tables are somewhat self-explanatory with the NAD data and section designation in the nested table, the verbal description of the intervals "offshore" where answers are needed on the left, and to the right the True vertical Depth (TVD) of each of those intervals with a HORIZONTAL distance calculated from each interval to the Surface Hole Location "onshore" (SHL). The known water wells column states the number of identified water wells that are wj hin 1/4 mile radius of the surface location in fi.. The other numbers in that column indicate the number of surface water wells, if one drew a cylinder centered on the point subsea and brought that cylinder to surface (the number of water wells in that 1/4 mile radius circle). See Well Spot Map and Tops of Injection Intervals. Disposal Well Area 1 Est Top of upper confining layer Depth requested Est Bottom of upper confining layer 1/4 mile radius of wellhead Est Depth of TDS above 3000ppm Est Depth of TDS above SODOOppm Est Too of injection zone Confirmed injection Injection area 1 Injection area 2 Injection area 3 Injection area 4 Est Top of lower confining layer Est Bottom of lower confining layer TD of well DW #1 Surface Location: NAD 27 x Y Lat Lon Sec 2 45 15w 168717 2144407 N 59 5127.58 W 15148 7.62 167554.8882 2143833.442 N 59 51 21.63 W 15148 30.05 167335.5549 2143725.191 N 59 51 20.50 W 15148 3419 166973.65 2143546.58 167554.8882 2143833.442 164790.3412 2142469.006 N 59 51 7.45 W 15149 23.42 from Hansen #1 166830.285 2143475.816 N 5951 18.31 W 151 4842.52 Upper Tyonek 166951.7216 2143535.751 N 595118.49 W 1514841.70 Lower Tyonek 8 164492.2643 2142321.891 N 59 51 5.92 W 15149 29,18 tarichkof (Lower Tyonek) 163697.5467 2141929.66 N 5951 1.84 W 15149 44.52 Hemlock 163394.8667 2141780.273 N 5951 0.29 W 1514950.36 Notreached Notreached Bottom Hole Location:1 Sec 30 4s 15w 162912.33 2141542.12 N 59 SO S7.81 W 15149 59.67 True Calt KNOWN Vertical Dist to Water Depth^ SHP Wells 0 0 2700 1295.9 3 3000 A51!9_4 0 3495 "' 1944,1 0 2700 AA 1295.9 3 6500 AA 4378.9 0 3583 "' 2104 3525 19_6_8.6 6889 4711.3 7976 5597.5 8390 5935 9142 0 9542 0 9050 6473.2 0 Est Top of upper confining laye Depth requeste Est Bottom of upper confining Jaye 1/4 mile radius of wellhea, Est Depth of TDS above 3000ppr Est Depth of TDS above 10000ppr, Est Top of injection zone Confirmed injectior Injection area Injection area Injection area Injection area Est Top of lower confining iaye Est Bottom of lower confining [aye TD of wel 2aa DW 1 and DW 2 Summary Table 4 Corrected.xisx DW Mt NAD 83 x Y Lat Lon Surface Location: ec 2 S4s 15w 1308740.567 2144162.087 N 59 51 25.3f W 15148 15.4 151.804292 1307578.436 2143588.567 N 59 51 19.42 W 151 48 37.89 59.855081 1307359.099 2143480.323 N 59 51 18.2f W 151 48 42.12 I 1306997.193 2143301.72 i 1304813.844 2142224.221 from Hansen rt1 1306910.487 2143258.93 N 59 511519 W 15148 50.78 Upper Tyonek 1306975.26 2143290.895 N S95116.32 W 15148 49.53 Lower Tyonek B 1304515.762 2142077.116 N 59 51 371 W 15149 37.01 Starichkof (Lower Tyonek) 1303737.189 2141692.884 N 5950 59.63 W 15149 52.35 Hemlock 1303418.346 2141535.533 N S95058.08 W 15149 58.19 Not reached Not reached Bottom Hole Location: Sec 10 4s 15w 1302935.805 2141297.396 N 59 50 55.60 W 15150 7.51 True Cale KNOW Vertical 0 Dist to N Depth^ SHL' Wate{ Wells Lat/Lona dec degrees Correct Lat Correct Long 59.857050 151.804292 59.855394 151.810525 mx) 1295.9 3 59.855081 151.811700 3000 1540.5 0 59.854565 151.813640 3495 " 1944.1 0 1700 " 1295 ', 59.851436 151.825423 b500 ^^ 4378" 0 59.854442 151.814106 3583 '' 2104 0 59.854533 151.813758 3575 19686 0 59.851031 151.826947 6889 47113 0 59.849897 151.831208 7976 5597.5 0 59.949467 151.832831 8390 5935 0 9142 0 9542 0 59.848778 151.835419 905U 61473 7 0 Disposal Well Area 2 Est Top of upper confining layer Depth requested Est Bottom of upper confining layer 1/4 mile radius of wellhead Est Depth of TDS above 3000ppm Est Depth of TDS above 10000ppm Est Top of injection zone Confirmed injection Injection area 1 Injection area 2 Injection area 3 Injection area 4 Est Top of lower confining layer Est Bottom of lower confining layer TD of well 2aa DW 1 and DW 2 Summary Table 4 Corrected.xlsx DW A2 Surface Location: NAD 27 x y Lat Long Sec 2 4s 15w 168896.464 2145030.939 N 59 51 33.7f W 15148 4.44 168508.6827 2145890.659 N 59 5142.14 W 15148 12.48 168498.115 214611162 N 59 5144.30 W 15148 14.57 168242.1783 2146481.506 167234.4456 2148715.674 N 5952 9.60 W 15148 38.94 from Hansen #1 168212.68 2146546.908 Upper Tyonek 168232.1216 2146503.802 N 59 5148.10 W 15148 18.22 Lower Tyonek B 167104.4226 2149003.938 N 59 52 12.41 W 15148 41.64 Stanchkof (Lower Tyonek) 166740.0323 2149811.8 N S95220.26 W 151 4849.21 Hemlock 166601.2489 2150119.486 N 59 52 23.25 W 15148 52.09 Not reached Notreached Bottom Hole Location:1 Sec 35 3s 15w 166380 2150610 N 59 52 28.0 W 151 48 56.68 True Calc KNOWN verticai Dist to Watei Dppih" SHL" Welk 0 2700 943.13 3 3000 1187.7 3 3495 1591.3 3168 2 320 2700 nn 6500 ^^ 4042.2 3583 " 1663 3525 1615.8 6889 4358.5 7976 5244.7 8390 5582.2 9142 0 9542 0 9050 6120.3 0 Est Top of upper confining lave Depth requester Est Bottom of upper confining lave 1/4 mile radius of we8heai Est Depth of TDS above 3000ppn Est Depth of TDS above 10000ppn Est Top of injection zone Confirmed injectior Injection area Injection area. Injection area Injection area Est Top of lower confining lave Est Bottom of lower confining lave TD of wel 2aa DW 1 and DW 2 Summary Table 4 Corrected.xlsx DW #2 Surface Location: NAD 83 x y Lot Long Sec 24s 15w 1308920 2144786 N 59 5131.57 W 1514812.27 59.858769 151.803408 1308532.247 2145645.733 N 59 5139-93 W 15148 20.32 151.805644 2700 943.13 3 1308431.686 2145868.698 N 59 5142.09 W 15148 22.40 3000 1187.7 7 59.862619 1308265.762 2146236.589 1307258.101 2148470.79 N 5952 7.40 W 15148 46.77 from Hansen #1 1308193.38 2146397.075 N 59 5146.67 W 15148 26.81 Upper Tyonek 1308255.705 2146258.885 N 59 5145.89 W 15148 26.06 Lower Tyonek B 1307128.088 2148759.059 N 59 52 10.20 W 15148 49.47 Starichkof (Lower Tyonek) 1306763.724 2149566.933 N 595218.05 W 1514857.04 Hemlock 1306624.951 2149874.623 N 59 52 21.05 W 15148 59.92 Not reached Notreached Bottom Hole Location:1 Sec 35 3s 15w 1306403.72 2150365 N 59 52 25.82 W 15149 4.52 Definitions ^ Vertical depth " depth from downhole point to surface at 90° " Generally defined here as TVDss+145' elev. " Vertical Section " horizontal distance" "" Based upon Pioneer logging analyis to prove area of injection in the annular disposal on Hansen ^^ Per Wayne Campaign Report and email correspondence 07/02/2014 SHL Surface Hole Location True Calc KNOWN Vertical 0 Dist to Water Depth,' SHL' Well, Lat/Lona dec decrees Correct Let Correct Long 59.858769 151.803408 59.861092 151.805644 2700 943.13 3 59.861692 151.806222 3000 1187.7 7 59.862619 151.807180 3495 "" 1591.3 3168 1320 2700 ^^ 9.868722 151.812992 6500 ^^ 4042.2 0 59.862964 151.807447 3583 •" 1663 0 59.862747 151.807239 3525 1615.8 59.869500 151.813742 6889 4358.5 0 59.871681 151.815844 7976 5244.7 0 59.872514 151.816644 8390 5582.2 0 9142 0 9542 0 59.873839 151.817922 9050 6120.3 0 CLASS I APPLICATION NO UNDERGROUND SOURCE OF DRINKING WATER RULING REQUEST COSMOPOLITAN FIELD DEVELOPMENT KENAI PENINSULA BOROUGH AND COOK INLET ALASKA General Information Request by: BlueCrest Alaska Operating LLC (owner/operator) 3301 C St Ste 202 Anchorage, AK 99503 Area of request: (Table 4 Summarizes Area Data) Disposal Well 1 Area in NAD 27 and NAD 83 NAD 27 x Y Lat Long Surface Location: Sec 2 4s 15w 168717 2144407 59.512758 151.495544 Bottom Hale Location; I Sec 10 4s 15w 163131.667 2141650 59.505894 151.495544 Nad 83 x y Lat Long Surface Location: I Sec 2 4s 15w 1,308,741 2,144,162 59.512538 151.481545 Bottom Hole Location: I Sec 10 4s 15w 1303155.14 2141406 59.505673 151.500327 Disposal Well 2 Area in NAD 27 and NAD 83 NAD 27 x Y Lat Long Surface Location: Sec 2 4s 15w 168896.464 2145031 59.513378 151.485668 Bottom Hole Location: I Sec 35 3s 15w 166380 2150610 59.522802 151.485668 Nad 83 x y Lat Long Surface Location; I Sec 2 4s 15w 1,308,920 2,144,786 59.513157 151.481227 Bottom Hole Location: I Sec 35 3s 15w 1306403.72 2150365 59.505673 151.500327 Page 1 Introduction BlueCrest Alaska Operating LLC requests that the United States Environmental Protection Agency (EPA) rule that the subsurface waters between 3000' TVD and 6500'TVD within 1/4 mile of the surface location indicated above and the bottom hole location indicated above DOES NOT QUALIFY as an underground source of drinking water (USDW) as defined in 40 CFR 144.3. It is requested that a "no USDW" determination be made on depths greater than 6500'TVD. This action will facilitate the permitting of one or more Class I waste disposal well(s) on the BlueCrest Cosmopolitan Field Hansen Pad to help minimize potential upset of surface waters by allowing injection of drilling, production, and camp waste waters, etc. NOTE: TVDss +145' elev = TVD. By separate documents, BlueCrest Alaska Operating LLC plans to request that the proposed well(s) to be drilled be utilized as a Class I non -hazardous disposal well. The formations identified for Injection are various zones in what is commonly called the T onek formation with some portion of the upper Hemlock. At a later date it is anticipated to request water flood authorization. Cosmopolitan Project Overview BlueCrest Alaska Operating LLC plans to develop the oil that is offshore by drilling extended reach and lateral tail wells from the Hansen Pad onshore. At present the development plans include 20 producing wells with 10 water flood wells. At some time in the future the plans include setting 1, 2 or more offshore structures and drilling ±6 wells each for gas production to be brought ONSHORE for processing and sales at the Hansen Pad (aerial in Figure 1). So, with the rather near term oil and associated gas and water production and the future gas production with associated liquids, there will be a major production facility installed on the Hansen Pad. Preliminary construction is to start later in 2014 with most completed in 2015. A workover on the existing well is being discussed to be done in the near term. Drilling is anticipated to start in 2015 with the first well to be the first Class I disposal well for the pad. There is also a proposed well OFFSHORE called the Cosmopolitan B-1. Discussion: BlueCrest Alaska Operating LLC proposes to demonstrate that the proposed area requested for the aquifer exemption meets the criteria of 40 CFR 146.4 Criteria for exempted aquifers. The proposed well(s) were designed to meet the criteria of the section as follows: (a) It does not currently serve as a source of drinking water There are no drinking water wells that penetrate the aquifers proposed to be exempted. Included Is Attachment A which describes the Area Geology and Stratigraphy. in addition, maps based upon the upper and lower confining zones are included which identify the relationship of the proposed zones to the producing structure. The discussion under (b) (2) below and the Attachment C identifies all of the known drinking water wells between Anchor Point and Ninilchik and identifies those closest to the project and discussed in the next paragraph. Two research projects (one fairly close and one about 60 miles away), show that the groundwater (drinking water) generally flows from east to west on the Kenai Peninsula. In addition, the typical drinking water sources are bound within confining layers and eventually flow to the Cook Inlet. The titles of the articles are Page 2 Petrik, W. A. 1993. Aquifers and Hydrology at Anchor Point, Alaska. Alaska Department of Natural Resources, Division of Water, Alaska Hydrologic Survey and Division of Geological and Geophysical Surveys, Public Date File 93-50a • Nelson, Gordon L. 1981. Hydrology and Effects foR Industrial Pumping in the Nikiski Area, Alaska. U. S. Geological Survey, Water Resources Investigations 81-685 These are available upon request. Attachment B provides maps and pictures showing the approximate location of the injection location AND the first injection well wellhead. Two criteria are addressed by BlueCrest. A greater than 1/4 mile buffer zone is provided to indicate the maximum extent of impact of the Class wastes within the iniection zone. There are 6 water wells in Sec 2 (surface), no water wells in Sec 3 and 10 (primary injection area), none in Sec 4 and 9, and POSSIBLY 7 water wells in Sec 11 which are slightly more than % mile away from the primary injection. The second criterion is that this is an application for more than 1 disposal well (which means the surface wellhead may be located in another area of the pad), so a 114 mile buffer zone at surface is requested for EACH of the potential disposal well surface location areas. Also an additional offshore disposal area is indicated. Table 1 provides a list of portions of sections at a minimum that are included in the buffer zone for the wellhead (pump down point). Table 2 gives a listing of the wells in those section segments. Table 3 lists the buffer areas for injection intervals (there are NO wells located). Table 1. Geographic location of Buffer for Wellhead of injection Well(s) Township Range Section Segment 4S 15W 2 NE V4 4S 15W 2 SE 114 4S 15 W 2 SW 1/4 Note: all segments are in the Seward Meridian Based on ADNR well data and interviews with nearby landowners, there are currently 6 wells located within this exclusion area. Of the 6 wells, 3 are reported to WELTS and 3 others were discovered by interviewing land owners. Of the 3 non reported wells (A,B,C in the table below and on the drawing), 2 have the capacity or, are used as a drinking water source. The third was used as a source of industrial water for drilling. Water wells A,B,C are within '/+ mile of the proposed wellheads but the others are in the section segments requested for buffer. Again see Attachment B. The deepest documented well is 101 feet is in Sec 2 which provides at least 1/2 mile horizontally and at least '/z mile vertical separation between the injection location(offshore) and the bottom of the water wells. Confining layers occur both on top and below the injection/disposal zone and the zones requested for exemption. Page 3 Table 2. Water Wells Section 2 Source: Alaska Department of Natural Resources, Information Resource Managrnent, Alaska Mapper Compa First Last fly �..,. LOU ID Name Name Name Swaffor ANCHOR d S004S015W02 NW NW POINT/ 86 22394 ROBERT WALLI Drilling NE NE STARISKI QQQQ THE WATER S004S015W02 SE SW CH MILLER LAS 30 17836 TERRY JORDAN CO SE SE L1, STARISKI 23411 L This is the well that is north of the northern lease boundary - owned by Peter and Shelly (Hansen) Jensen. The well is drilled to 30-35 feet, with a hand pump (not plumbed to the cabin). 35 It is 100' north of the lease line and 100' in from the bluff A line Is the well at John Hansen's house - it is 150' southeast of the southeast comer of the residential structure. It is also 30 - 35 feet in depth. 34 There are three other "abandoned well attempts" in a 250' radius B from the Hansen house - some are cased and capped. They were replacing the pump. While lowering the new pump into the well the "chocks" gave way and the pump and some length of pipe fell to the bottom of the well. He states this well is "way over 100 feet deep". I believe they make a retrieval tool for this situation. I am still researching who ,141 was involved with that episode and who drilled the well originally - not having much success. Will update as new info comes in. C The well will be re -activated or PLUGGED by BlueCrest. CH MILLER THE L2, 30 WATER S004S015W02 SW SE STARISK 17835 GEORGE MILLER CO SE I QQQ "END OF REPORT— Table 3. Geographic location of Buffer for DOWNHOLE Injection Zones No water wells are located in these SECTIONS Township Range Section Segment 4S 15 W 3,10,19 ALL 3S 15 W 34,35 ALL Note: all segments are in the Seward Meridian Pian views of proposed injection wells with 1/4 mile tick marked FOR requested buffer zones are attached in Attachment F and are based upon the proposed directional drilling plan. Also see Table 4. (b) It cannot now and will not in the future serve as a source of drinking water because: Page 4 (1) It is mineral, hydrocarbon or geothermal energy producing, or can be demonstrated by a permit applicant as part of.... The Class I injection well(s) will be located mostly within the Tyonek formations which commonly can produce oil and gas in the general area. Hydrocarbon resources are not however expected to be found within the specific zones in the proposed disposal well(s). If it is, it should be far down structure from proposed wells that can produce it. By offset correlations, it appears that the proposed zones may contain hydrocarbons but not in quantities that are presently deemed commercial. Reference — Structure Maps E-1, E-2. (2) It is situated at a depth or location which makes recovery of water for drinking water purpose economically or technologically impractical; Drinking water wells within 114 mile (and greater) of the proposea disposal wellhead were catalogued from DNR Dept. of Hydrology WELTS and by face to face meetings of the local citizens (Attachment C). The deepest water well along the coast between Ninilchik and Anchor Point was drilled to a depth of 380 feet (most wells in the near area only drilled to 35 feet or less). The depth of the proposed injection interval is below-3380'TVDss AND offshore from the disposal WELLHEAD. Water wells can certainly be drilled to deeper depth and deviated, however, there are no economic incentives to drill to deeper depths to obtain adequate water supplies as they would have to be shallower than 3350'TVDss and thus technically and economically impractical. The estimated scoping cost of the proposed well(s) is presently ±$15,000,000 so to drill to the lower depth for water when so many other sources are available, is economically impractical. Based upon the attached "proposed" directional plan, a TVD of-3350'TVDss (3495'TVD) in that well path of DW 1, is +1/3 mile from the surface well location. See Table 4. In addition, if it were planned to initiate a new water well by the utility, the following is an estimation of what the HIGHER cost would be once the water was pipelined to a subdivision or city. Amortization Calculations uttutg Costs wortttlly) est Cost ul Service' Anchor Pt Vino avg indiv Well !Loan Amount 520, 549,U00 Chemicals $1,000 Foca; Monthiy :Interest rate 3.50°/. Labor & ourden $20,000.00 Cost/ga 1 $0.02 $0.01 Months 360 Utilities $1,000.00 CosUfamily $71 $30 Monthly Payment Maintenace $3,000.00 MISC testing. etc $3,000.00 Families nitmly Monthly useage/person Montivy Co 100 4 1000 Useage,4110 400000 yaunto The cost per gallon to recoup the capital outlay and monthly costs is $0.30/gal vs the existing cost of $0.02/gal thru the utility and $0.0075/gal for a personal water well. (3) It is so contaminated that it would be economically or technologically impractical to render that water fit for human consumption: pr... Page 5 The proposed zones to be exempted are more than % mile "below" presently utilized drinking water reservoirs and generally more than 113 mile horizontally away from presently utilized reservoirs. The cost to reach these would deem them economically impractical to reach them and the treatment of that water for human consumption would be impractical. See the water analysis included in the attachment for (c) below. (4) It is located over a Class III well inining area...: or This is NOT APPLICABLE Page 6 (c) The total dissolved solids content of the ground water is more than 3000 and less than 10000 mg/1 and it is not reasonably expected to supply a public water system. The proposed disposal zone is within the Tyonek/Hemlock Formations below -3380' TVDss and above -8,605' TVDss. Total Dissolved Solids (TDS) levels for this interval from available Well Logs with other data for this interval including a water analysis by Mr. Wayne Campaign with Waters Petroleum in Attachment D and D-1. Those conclusions indicate that the TDS values are generally above 4,500 mg/I below 3000'TVD. Therefore it is concluded that the proposed injection intervals would NOT be considered a source for drinking water at any time. The lower part of the proposed zone may have a TDS in excess of 10000mgl. The affected strata are those portions of the Tyonek and Hemlock zones that are stratigraphically equivalent to the interval from 5175' MD /3339'TVD—down to 16823'MD/6693'TVD in the Hansen #1 and then to the upper Hemlock as seen in the Starichkof and Cosmopolitan State #1. The proposed exempted aquifers are mostly in the Tyonek formation with some upper Hemlock which is part of the Kenai Group. The Tyonek and Hemlock are in the lower part of the group. All members have been known to produce oil and gas in the Cook Inlet Basin. They are Tertiary - aged, fluvial —derived reservoir and non -reservoir deposits. The nearby Hansen #1 well had annular injection and an analysis via a temperature survey indicated that injection was occurring BELOW a claystone coal sequence in the Tyonek zone and injecting at ±6030'MD /3583' TVD. Although it is requested to be part of the exemption, this is confirmation that the interval between 51751MD and 6030'MD on the Hansen does function as a confining zone. The proposed injection zone(s) is mostly in the Tyonek Formation below that point and possibly the top of the Hemlock. A description of upper and lower anticipated confining layers is discussed in Attachment E with confining zone structure maps in EA and E-2. Page 7 FIGURE 1 2aa DW i and DW 2 Summary Table 4.xlsx Table 4: Area Summary This "group" of similar tables, summarizes the ENTIRE potential wellbore for EACH of the disposal areas. For each disposal well there is a NAD 27 table and a NAD 83 table. The NAD 83 wellbore location data is "calculated" from the NAD 27 data using an in-house algorithm so there may be some slight differences if EPA verifies the data with an in-house program. The tables are somewhat self-explanatory with the NAD data and section designation in the nested table, the verbal description of the intervals 'offshore" where answers are needed on the left, and to the right the True vertical Depth (TVD) of each of those intervals with a HORIZONTAL distance calculated from each interval to the Surface Hole Location 'onshore" (SHL). The known water wells column states the number of identified water wells that are within 1/4 mile radius of the surface location in The other numbers in that column indicate the number of surface water wells, if one drew a cylinder centered on the point subsea and brought that cylinder to surface (the number of water wells in that 1/4 mile radius circle). See Well Spot Map and Tops of Injection Intervals, Disposal Well Area 1 Est To Est Bottor 1J Est Dept Est Deptt Est Tol Est Botton Est Top of upper confining Iaye Depth requeste Est Bottom of upper confining Jaye 1/4 mile radius of wellhea Est Depth of TDS above 3000ppn Est Depth of TOS above 10000ppn Est Top of injection zon Confirmed injectior Injection area Injection area Injection area: Injection area j Est Top of lower confining Iaye Est Bottom of lower confining Iaye. TO of wel Surface Location: Surface Location: NAD 27 x Y Lat Lon I Sec 2 4s 15w 168717 2144407 59.512758 151.480762 of upper confining layer 2143588 567 59 511942 167554.8882 2143833 442 59.512163 151.483005 Depth requested S9511829 151 484112 167335.5549 2143725.191 595120-50 151.483429 r of upper confining layer 166973.65 2143546.58 2142224 121 59.510524 4 mile radius of wellhead from Hansen p1 1306910 487 2143258.93 59.511599 151 485078 h of TDS above 30Wppm 1306975 16 2143290 895 167554.8882 2143833.442 59.512163 151.483005 of TDS above 10000ppm 2142077 116 59 510371 164790.3412 2142469 006 59.510745 151.492342 Est Too of injection zone from Hansen it1 151.495204 166830.285 2143475 816 59.511791 151.484404 Confirmed injection injection area 1 Upper Tyonek 166951.7216 2143535 751 59.511853 151 484170 Injection area 2 Lower Tyonek 8 Notreached 164492.2643 2142321.891 59 510592 151.492918 Injection area 3 tarichkof (Lower Tyonek) 59.50556 163697.5467 2141929.66 59.510184 151.494452 Injection area 4 Hemlock 163394.8667 2141780,273 59.510029 151 495036 of lower confining layer Not reached of lower confining layer Not reached TO of well Bottom Hole Location: Sec 10 4s 15 162912.33 2141542.12 59.505781 151.495967 Est Top of upper confining Iaye Depth requeste Est Bottom of upper confining Jaye 1/4 mile radius of wellhea Est Depth of TDS above 3000ppn Est Depth of TOS above 10000ppn Est Top of injection zon Confirmed injectior Injection area Injection area Injection area: Injection area j Est Top of lower confining Iaye Est Bottom of lower confining Iaye. TO of wel Surface Location: Ned 83 zLat Lon Sec 2 4s 15w1308740.57 2144162,09 59.512538 151.481545 1307578.436 2143588 567 59 511942 151 483789 I 1307359 099 2143480 323 S9511829 151 484112 I 1306997 193 2143301 72 1304813.844 2142224 121 59.510524 151 493126 from Hansen p1 1306910 487 2143258.93 59.511599 151 485078 Upper Tyonek 1306975 16 2143290 895 59 511632 151 484953 tower Tyonek B 1304515.762 2142077 116 59 510371 151.493701 Stanchkof (Lower Tyonek) 1303737 189 2141692 884 59.505971 151.495204 Hemlock 1303418.346 2141535 533 59 SO5808 151 495819 Not reached Notreached Bottom Hole Location Sec 10 4s 15 1302935.81 21412974 59.50556 151.500751 0 0 2700 3000 0 3495 " 0 2700 ^^ ;. 6500 nn 0 3583 0 3525; :+ r 0 6889 J111,3 0 7976 }59715 0 8390 0 9142 0 9542 0 9050 5aT3.' 0 2 700 1295.9 3000 15405 0 3495 " 1944.1 0 2700 "" 12959 6500 ^r. 4378.9 0 3583 " 2104 0 3525 1968.6 0 6889 4711.3 0 7976 5597.5 0 8390 5935 0 9142 0 9542 0 9050 6473.2 0 Disposal Well Area 2 Est Top of upper confining lay Depth request( Est Bottom of upper confining lay 1/4 mile radius of wellhei Est Depth of TDS above 3000ppr Est Depth of TD5 above 10000pp+ Est Top of injection zon Confirmed injection Injection area Injection area Injection area Injection area Est Top of lower confining Jaye Est Bottom of lower confining Jaye TD of we] Est Top of upper confining lay( Depth requeste Est Bottom of upper confining lay( 1/4 mile radius of wellhea Est Depth of TD5 above 3000ppr Est Depth of TD5 above 10000ppr Est Top of injection zon Confirmed injectror Injection area injection area injection area Injection area Est Top of lower confining Jaye Est Bottom of lower confining Jaye TD of wel 2aa OW 1 and OW 2 Summary Table 4.xlsx Surface Location: NAD 27 x Lat Lon Sec 2 4s 15A 168896.464 2145030.94 59.513378 151.465668 •r 168508.6827 2145890.659 59.514214 151.481248 d 168408115 2146113.62 59.51443 151.481457 r 168242.1783 214648;.506 151.48224 r 1 d 2146236.589 i t 167234.4456 2148715.674 59.52096 151.483894 from Hansen #1 168208 7639 2146555.587 59.51486 151.481871 Upper Tyonek 168232.1216 1146503 802 59.51481 151 481822 Lower Tyonek B 167104.4226 2149003 938 59.521241 151 484164 tarichkof (Lower Tyonek) 166740.0323 2149811.8 59.522026 151.484921 Hemlock 166601.2489 2150119 486 59.522325 151 485209 151 485704 Not reached 1306624 951 2149874 623 59.522105 Notreached Bottom Hole Location: Sec 35 3s 15 166380 2150610 59.522802 151.485668 Surface Location: NAD 83 z Y Lat Lon Sec 2 4S 15v" 1308920 2144786 59.513157 151.481227 r 1308532 247 2145645.733 59.513993 151.482032 1 1308431,686 2145868.698 59.514209 151.48224 r 1 1308265,762 2146236.589 1307258 101 2148470 79 59.52074 151 484677 from Hansen a 1 1308193.38 2146397 075 59 514723 151 482735 Upper Tyonek 1308255 705 2146258 885 59.514589 151 482606 Lower Tyonek B 1307128 088 2148759 059 59S2102 151484947 tarichkof (Lower Tyonek) 1306763 724 2149566 933 $9521805 151 485704 Hemlock 1306624 951 2149874 623 59.522105 151 485992 Notreached Not reached Bottom Hole Location: Sec 35 3s 15 1306403.72 2150365 59.522582 151.490452 Definitions ^ Vertical depth " depth from downhole point to surface at 90' " Generally defined here as TVDss+145 elev. Vertical Section " horizontal distance" Based upon Pioneer logging analyrs to prove area of injection in the annular disposal on Hansen ^^ Per Wayne Campaign Report and email correspondence 07/02/2014 SHL Surface Hole Location 0 2700 943.13 3000 1187.7 3495 1591.3 3168 2700 ^^ 6500 ^^ 4042.2 0 3563 ' • 1672.6 0 3525 1615.8 6889 4358.5 0 7976 5244.7 0 8390 5582.2 0 9142 0 9542 0 9050 61203 0 2700 943.13 3000 1187.7 3495 1591.3 3168 1320 2700 ^^ 6500 ^^ 4042.2 0 3583 ' • 1671.6 0 3515 1615.8 6889 43585 0 7976 52447 0 8390 5582.2 0 9142 0 9542 0 9050 61203 0 Well Spot Map and Tops of Injection intervals rte. Pennzoil 20 21 ,D,pp BlueCrest PIonM Cosmo slate 26 Hansen COP.AK CCP AK Pennzoil Hansen Hansen i 00 i Starichkof St 32 :3, BlueCrest - PROPOSED Cosmo 22 23 27 26 8 34 Dw•s 35 V IV, 1i Map Key for 1/4 mile radius DW 1 Injection Horizon (Formation name) Dist. from surface wellhead Upper Tyonek 1968.57' Lower Tyonek B 4711.27' Starichkof (part of the Lower Tyonek) 5597.51' Hemlock 5935.05' TOP Lwr Confining Zone 6466.63' Black 6113.81' DW2 Dist. from Circle Color Code surface wellhead LIGHT PURPLE 1615.76' Dark Purple 4358.46' Burnt Orange 5244.70' Green 5582.23' TOP Lwr Confining Zone 6466.63' Black 6113.81' Sta ri ch kof State #1 K.B. = 68' 1 ' i • y - J. • K �4 - t -44 1 1 i I m tz Upper Tyonek Lipper Tyonek 2280' 4186' MD -2212' TVDSS -3350' TVD55 Lower Tyonek lower Tyonek 5662' S526' MD 5594' TVDSS -6744' TVDSS Starlchkof Starichkof 6749' 9929' -6681' TVD55 -7831' TVD55 Hemlock Hemlock 7148' 10462' MD -7080' TVDSS -8245' TVDSS rn Q3 ofi# 0_ 0Q. g fY ' a s ... 0) �, M c� 43 0 0 Upper Tyonek Lipper Tyonek 2280' 4186' MD -2212' TVDSS -3350' TVD55 Lower Tyonek lower Tyonek 5662' S526' MD 5594' TVDSS -6744' TVDSS Starlchkof Starichkof 6749' 9929' -6681' TVD55 -7831' TVD55 Hemlock Hemlock 7148' 10462' MD -7080' TVDSS -8245' TVDSS Attachment A Area Geologic Structure and Stratigraphy Structure The Cosmopolitan/Hansen Field structure is a NE/SW doubly plunging asymmetric anticline bounded along its west flank by a high angle reverse fault that strikes parallel to the structural axis. This structure, which is four and one-half miles by 2 miles, has approximately 600 feet of vertical closure over an area of over 6,000 acres at the Hemlock Sand Sand (Exhibit 1). Structural control includes six wellbores, three of these are vertical and penetrate the entire geological section on the structure and three extended reach wells drilled from the Hansen shore -side drilling pad, 3D seismic acquired by Pioneer Resources in 2005, dip meter data in two of the vertical wells, and migrated 2D high resolution seismic data acquired by GeoTek Alaska, Inc. in 2013. We have used 3D seismic data tied to all of the wells to generate several levels of structure maps. Although there is a 300 to 500 ms seafloor reverberation effect on the 3D data, the shallow high resolution GeoHaz 2D seismic shows that this structure is typical of parallel folding (Exhibit 3) and projecting shallow dips to deeper horizons gives a close approximation to the structure at depth (Exhibits 4 & 5). There are no known faults present at the planned water disposal well location. However, we do not have adequate seismic coverage to image the immediate area of the planned wellbore. At the stratigraphic levels of the injection zones known faults related to the Cosmopolitan structure include northwest to southeast trending normal faults situated at the north and south plunge of the anticline and one 80 foot normal fault that cuts the Starichkof interval in the Cosmopolitan State #1 well at a depth of 6,720 feet. None of these faults project into the area of the planned water disposal well. The first planned well will be drilled from the Hansen surface lease to an offshore bottom hole location in the NE/4, Section 10, T4S, R15W (planned x = 163132, y=2141650) which is well below the structural closure and approximately 1,200 feet low to the Pennzoil Starichkof St Unit #1 at the top of the lower confining zone. Stratigraphy Approximately 8,600 feet of Tertiary age Kenai Group non -marine sedimentary rocks are present at Cosmopolitan. The Kenai Group is represented here by 1,010 feet of the Beluga Formation (USGS unpublished data) characterized by thin bedded sandstones, coals and siltstone and silty shale intervals that were deposited in a braided stream environment. Based on seismic data and log correlation we estimate approximately 1,050 feet of Beluga was penetrated in the Starichkof State Unit #1 well, about 500 feet was present in the Starichkof State #1 and it appears to be missing in the BlueCrest Cosmopolitan State #1 well. The thickness difference across the Cosmopolitan structure is related to erosion and does not represent depositional thinning. The overlying Sterling Formation is not present and has also been removed by erosion. Unconformably underlying the Beluga sequence is 5,945 feet of the Miocene age Tyonek Formation, a basin wide series of fluvial conglomerate, conglomeratic sandstone, sandstone, coal, siltstone and shale which represent deposition in meandering streams, associated fluvial sediments and iacustrine environments. It is a major producer of both biogenic natural gas and oil throughout the basin and is charged with gas and oil at Cosmopolitan. BlueCrest Energy, Inc has informally divided the Tyonek into an upper section that contains gas productive sandstones and a lower interval that is predominately oil prone. The two zones are separated by a laterally correlative shale section that is easily recognized in all of the existing wells. The lowest section of the lower Tyonek, from 6,742 to 7,104 feet MD has been referred to as the "Starichkof" zone by Conoco/Phillips, Pioneer Resources and by BlueCrest Energy, Inc. and is the oil discovery zone found in 1967 by Pennzoil in their Starichkof State #1 well. Immediately underlying the Starichkof (lower Tyonek) is the Oligocene Hemlock Conglomerate. It was drill stem tested in the Starichkof State #1 well and recovered brackish water from two separate intervals beneath the now generally accepted oil/water contact at approximately -7030 ft. Conoco/Phillips tested water free oil in higher structural positions in both the Hansen 1 and Hansen 1A wells. The Hemlock generally consists of medium to coarse grained thick bedded sandstone with substantial conglomeratic beds and lenses. In the Starichkof State #1 well it is 485 feet thick and in the Cosmopolitan State #1 it is 500 feet thick. Underlying the Hemlock is the Paleocene to Eocene age West Foreland formation, a 1,155 feet thick sequence of volcanic tuffs and volcaniclastic sandstones and siltstones devoid of oil or gas shows and without reservoir quality rocks. The West Foreland unconformably overlies the Upper Cretaceous marine Matanuska Formation, and at least 3,339 feet of shale containing an abundance of inoceramus shells. SEE ATTACHMENT E-3 for a map on the BASE of the ProducingStructure as anticipated. C U tiS Q A tiA'IjL 4 NHL: 2 1 A E i r E N T S N., 7i ..' * T F F1 2 1 -AT: -5:� r- ''30,'-92 I f3 21,17 (SL NOTES .11 A&. A I:, A-,,J'k Lt* =L F ,. -1, kir=1S OF K- fv Of. 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W W oW o0 000 U mm �=mm ✓, 0 W uj a W W 2 ¢a I. - as �Qa In >.z W ¢ uj LL z ��c"i'u QuvV�QCmz� o� 3� ='zd 3¢x 4 U) JJ �S mm raaV/Qz¢0=,p nc�� 3rmU�x S� 0 LU <cc 3 0 2� S� W m i3:38n iz3 zz o aa0u c 4 a v 2 o c s N o s7:nnm myon V)c� t c t t i N N N N of cvNN NN ZY Cli N� NN ¢2aQs J ATTACHMENT D Wayne Campaign Waters Petroleum Advisors Petrophysicist To: Stephen Hennigan From: Wayne Campaign Subject: Shallow Salinities, Hansen Area, Cook Inlet, Alaska Date: lune 30, 2014 I was request to perform shallow salinity analyses for the Hansen area in the Cook Inlet. This memo will document that effort. I will refer to several other letters on the topic from public AOGCC files authored by myself, as well as new work from recent wells. Salinity is calculated from an industry standard technique called Rwa. This method assumes a zone is water saturated and just reverses the Archie Equation to solve for "Apparent" Rw. Salinity is then derived from that result. EPA documentation used the Humble formula for formation factor and that is what I have used in this instance. Equations are as follows; Rwa = (1)2.15* Rt/0.62 0 = porosity in decimal Rt = formation resistivity Formation Temperature = 0.0138*TVD+40 Salinity= 10^3.562—Log(RW@75-0.0123)l 0.955 J This gives salinity in ppm NaCl equivalent. The appendix to this memo looks at a well with complete data as a proof of the technique. The original Hansen well was also analyzed for shallow salinity and documented in a letter of November 9, 2001` . The log attachment to that letter is included. We acquired continuous porosity and resistivity data from measured depths of 3530'-5140' (2693-3153' tvd) and I have evaluated this data for Volume Shale, total porosity (PHITT), and Apparent Water Resistivity (Rwa). included is a log presentation of resistivity and porosity logs plus evaluation of Vshale, a coal flag and Total Dissolved Solids calculation, highlighted in dark blue in the sands. Presented in the porosity track on the left, is the total porosity curve in red. This well is deviated 73° from vertical and there will be some problems with thin bed responses (see log, depths 4162' and 4170') where the TDS calculation will be in error. Another complication is intervals of high carbonaceous, or organic content, often in the form of detrital coal. These can be picked out where neutron and density porosities are quite high yet not enough to trigger the coal flag. Several are noted at the bottom of the log. Inspection of the TDS curve in the thicker sands indicate we are at 4500 ppm salinity at the top of the interval and increases to around 6000 ppm NaCl equivalent near the bottom. F�S, LEUM ADVISORS' Wayne Campaign Waters Petroleum Advisors Petrophysicist Salinity was calculated in the Anchor Point well for the original Cosmo Prospect. That letter of May 10, 20013 is also part of the AOGCC records and conclusions are presented here and in Figure 1. "Evaluation of the Anchor Point offset well show salinity to be less than 500 ppm Total Dissolved Solids above a depth of 200 feet. From 300' to 3400', TDS calculates at 2200 ppm (NaCl eq.). Salinities in the interval 3500' to 6500' are 4000 ppm. Care must be taken through this section to recognize the gassy and coaly sands. These give erroneous porosity estimates which skew the Rwa results. These sands are coded red on figure 1. Below 6800', salinity rapidly increases to 16000` ppm TDS. The SP is of little help in the fluvial section above 7000', but is much more comparable below." 504 100( 1501 2 00C 2 50C 3 000 W w I_ 3 500 1-- 4000 a. w 0 4 500 5000 5500 6 000 6 500 7 000 7 500 TDS / DEPTH Crossplot Well: ANCHOR _PT_1 Filter: SP < -20 & COAL = MISSING & DT > 80 ,s s 4 saw—ft ® Sand of Interest mover Coaly, Gassy ........go AInterval a�rrr. • Y N . v a o o v O C C O q O ® O N 4 "Q OD O N Total Dissolved Solids (Kppm ) C otor GAS SHOW Fig 1. This is a plot of TDS values calculated from the Rwa technique, versus measured depth of the Anchor Point 1#1 well. The data has been filtered to eliminate coals, tight streaks and shales. Intervals that correlate with gas shows from the Mudlog have been coded red. SP calculations are the red ovals and show poor correlation until salinities exceed 10000 ppm. The scatter at the bottom of the plot is due to thin, low quality, low porosity sands. F'F q S P'E l,-VVX7�5S'�!IRCLEUM ADVISORS, Wayne Campaign Waters Petroleum Advisors Petrophysicist |n2O13,Buccaneer drilled the Cosmo #1onthe top ofthe structure. The well intersected several gas sands and afew water sands. Fig. 5/sthe calculated salinities for this well. TD5averages about 115OO ppm tothe top oythe West Foreland, where salinity jumps toJ2OODppm. Cosmo #1 Salinity from Logs 2000 ----- - - aouo --00_ 4o00 - ---- — -- _- doou -1 00 loom ; 40 _ OF a .MW am ^ | 5000 10000 5000;-) os�m Co 2060-',;*-1e1160ttUs71t 76 10 5'12,2014 15)-i Hg. 2Cosmo wzsalinity from logs. Because oyall the gas sands, data had been discriminated by5waswell asporosity and vdav. Salinity isgreater than z8OUUinall the logged sands .nthis structurally high position. 4VATERs PETROLEUM ADVISORS� Conclusions. Wayne Campaign Waters Petroleum Advisors Petrophysicist 1. Rwa technique provides reasonable answers as shown by the Ninilchik examples. 2. Presence of bicarbonate will bias calculated salinities to artificially low values. Low salinity Cook Inlet waters tend to be high in the bicarbonate ion. 3. Water salinity in the original Hansen well exceeds 4500 ppm below 2700' TVD. This number is likely low due to conclusion #2. This well is approximately 1 mile north of the proposed injection area. 4. The Anchor Point well salinities reach a value of 4000 ppm below 3600' and maintain that level to a depth of 7000', where salinity increase to 16000+ ppm. This well is 6 miles due south off the propsed injection area. 5. The Cosmo well was drilled high on structure and salinity exceeds 10000 ppm below 2200'. This is confirmed by an analyzed water sample recovered from 2488' in the well. This well just over 3 miles to the NW of the proposed injection area. 6. Interpolating between these wells, we expect TDS to exceed 4500 ppm below a depth of 3000' at the proposed injection location. Salinity should remain constant at least to a depth of 6500', where is will exceed 10000 ppm. If you have any questions or comments, feel free to call on me. Thank you for this opportunity to serve you. Wayne Campaign _-eii 907 602.3085 noerre 940 0-9-2232 wcampaignPwatersUetro.c:om i L--t't2i frOM'Nay;ly L'--aW,•)dlgl; °Iohfif.- 2. SCII!Uinberger Chank 3ooK 2U(.' -i JE1:t)i• �lydil r ;: �'� r.. ,;.�lc�ll ,�. ��;;,• Y j. !-yetter`m, IroVVay:,,e �a ll) tok?' �1-jv°. )d.il llt�: i i._ir we ,)iol 4. i` V iQ C eJ �r `,l l 1 4 4 6 e S Wayne Campaign Waters Petroleum Advisors an&= Petrophysicist Appendix: Proof of Technigo- The Ninilchik #1 well includes a DST in a shallow section, and a complete salinity lab analysis of the recovered water. This dataset is included solely as a proof of the techniques used in this application. Figure 1A is the lab analysis of the water obtained in a DST from this well. Figure 2A is a plot of the logs for this well. Track 1 includes the SP, coded to delineate the sands, and a Total Dissolved Solids curve from the equations given previously. This curve is colored dark blue in the sands and light grey elsewhere. The inputs to these equations are given in the figure caption. The DST interval is highlighted in pink. These values give a "Apparent NaCl" salinity of around 1400 ppm though the lab analysis shows 2485 ppm while giving a very similar water resistivity value. The log technique assumes the only ions are sodium and chloride. Cook Inlet waters contain significant bicarbonate ions (HCO3-). This is a large ion with reduce activity compared to Na+ and Cl- ions. Chart Gen -4 (Fig. 3A)2compares the electrical activities of the various ions. Note the bicarbonate ion has about 1/3 the electrical activity of the same concentration of sodium or chloride. The equation in Figure 3A uses the concentrations from the lab report, with the multipliers from Figure 3A to calculate an "Apparent NaCl Salinity" of 1496 ppm of NaCl equivalent salinity, though the lab value is 2485 ppm. In this example, bicarbonate comprises 60% of the measured TDS while the Rwa technique calculates only 56% of the actual TDS. The dataset indicates the measured and calculated Rw values are quite similar. Error is introduced in the conversion of water resistivity to TDS. The log model assumes all salinity is sodium and chloride. Presence of bicarbonate introduces error. it is important to note the direction of this error. In the presence of bicarbonate, log calculated salinity will always be LESS than actual salinity. We can treat the calculated salinity as a lower limit. The magnitude of the error is a function of the percentage of bicarbonate. Unfortunately, we have no way of estimating % bicarbonate from the logs. There are also few lab measured, low salinity water samples from Cook Inlet tests. The few I am aware of (Sunfish 1, Sturgeon, Ninilchik, Canary Loop) do have a high percentage of bicarbonate. I � ETERS PETROLEUM ADUlSORS Wayne Campaign Waters Petroleum Advisors Petrophysicist 1L ANALYSIS OF WA OATI Or REPORT �, i+~ r'1 y /i r' .' *ELI NO. DATE t.Z► 5AMPLING CI GROUP COMPANY CARBONATE SAMPLED UY MISCELLANEOUS i I ELD 04CO3 y LABORATORY NO ;.", �_.; .'/� 20NE EARTHS ANALYST I C D I D E SAMPLE SOURCE Jd RA ICAI.I.S SILICA PAR75 PER MELj10.i, _ REACTING _YAi.uE REACTING VALUE IRON , A{.GN4 INA 8203 M11LIf:»AMS PEP LITER EQVIYALFNT1 PVR MILE(Oft P{ACENI 501) 0.M CafEARTH5 lA 1�', CAL C i L+M C G,`(; CHLORIDE 5ALIh1Tl MAGNESIUM My^• 'yPFLIFIL GRAITV SULPHATE SALINITY BARIUM $a �� ��. PH C S T R O N T 1 Ct M Sr Na •x TICK ELL GRAPH SULPHATE $04 CHLORIDE CI GROUP CARBONATE cc 3 MISCELLANEOUS BICARBONATE 04CO3 y PRIMARTSALINITY 7(�y' HYDROXIDE OH EARTHS [T. ` I C D I D E G ,LU HYDROGEN SULF I DE. i_ P- / SILICA 5102 PRIMARY ALKALINITY T['+,�j(i IRON , A{.GN4 INA 8203 WEAK ACIDS y,..l TO T AL_�,_� GROUP CHEMICAL CHARACTER MISCELLANEOUS ALKALIS YY / PRIMARTSALINITY 7(�y' BORON PPM EARTHS [T. ` SECONDARY SAL I N I TY G ,LU HYDROGEN SULF I DE. i_ P- / STRONG ACIDS PRIMARY ALKALINITY T['+,�j(i EQU1I.A[.ENT SALT G/G WEAK ACIDS y,..l 5E CON aARY ALK AL INITI/.�V� RESIST;tiIT'r ! 17L'I .° 0.M CafEARTH5 lA 1�', CHLORINITY .i G,`(; CHLORIDE 5ALIh1Tl 'yPFLIFIL GRAITV SULPHATE SALINITY H� �; CARBONATE/CHLORIDE �� ��. PH C REMARKS Na •x TICK ELL GRAPH yc 7- i ,Y 77.1 '- ., ��� ' -k 9•FewcllNc �ALuI �- F G. ,Pi �r:a 4 F, Ve C4./r1c .' '4 d�'BQ�S' cc,I+cr iG4 U ARC RLYRfSEN15 '(:4N,GE1d7Nw/71 GN Of SOL; pla_S�So' h31iM/A6 5�1+r� rA�tyEA�� oRo-391 . V.S.A..6-54? f+ �d l� _ -tsw� r+dt�L !f t • a—: rIMTID Ir U.S.S1C+NIC' Fig. 1A. Lab analysis for Ninilchik water sample. Note high Bicarbonate and lab measured Rw. I N I I (' 1 1 1 1. �l Wayne Campaign Waters Petroleum Advisors Petrophysicist TOSS -1 DEPTH iD E; 5 csNu�u r o Kr►�u t1 Ea 11 U M AA M — — — -. -.. -' _.. — — — — — — ICY) A4 3700 .-Pami .�► ,ir ..: 4W —� 000 DST rrr• +, 3800 N - a t MC ... ti 1 • / f #. i► 3900 - --�...� __,...... ..,...............�.- -....-. .,.�... Fig. 2A. Ninilchik log data. Pictures the interval that was tested and obtained the water sample of Figure 1. Average sonic value used was115 µs/ft and Rt of 23 0-m to give Rwa value of 3.64 Q -m @ 75°F, Lab measured Rw (Fig. IA) was 3.62 S2 -m @ 77°F. Apparent TDS in track 1 is colored dark blue in the sands (defined by SP) and gray elsewhere. You can see how Rw can vary from sand to sand, as defined by this technique. F�s 7. F!rF,tAtli,�t�t5'1 `P I t L112 5) U-1;5 5, Wayne Campaign Waters Petroleum Advisors Petrophysicist If 1 n 'Illi, I Oil,1 )lll, ', IllI aft; Ns IhAl tl ,, , Ili, I as ), il.. ,. 111#, .' !a Fig. 3A. Plot of ionic activity levels (courtesy Schlumberger). If we use this chart with the Niniichik data, we can convert to "NaCl equivalent" salinity. "NaCl eq." = 724*1 + 10.S*1.3 + 0.5*2 + 50.6*0.8 + 50*1 + 150.6*1.04 + 1499.2*0.34 = 1496 Sodium Calcium Magnesium Sulphate Chloride Carbonate BiCarbonate Sub Attachment 0.1 Attachment E Confining Zones This discussion applies to the easterly flank of the structure, North and South of the Hansen well. Upper Confining Zone The base of the Upper Confining zone is at 5,123 feet MD (-3,150 TVD -ss) in the Hansen #1 well and exceeds 2,000 feet in thickness. The interval is laterally continuous across the Cosmopolitan area and is recognized in all of the wells. The Upper Confining zone consists mostly of shale, claystones, relatively thin coal beds and minor discontinuous sandstone lenses. This shale dominated section acts as a vertical barrier to fluid migration as was evidenced during Pioneer's injection in the Hansen 1 in the interval from 5,132 feet MD to 5,530 feet measured depth in which all fluids were contained in the injection intervals beneath this confining zone. Lower Confining Zone The Lower Confining zone is the 1,184 feet thick West Foreland Formation as defined in the Starichkof State #1 in the interval from 7,589 feet MD ( -7,521 feet TVD -ss) to 8,773 feet MD (-8,705 feet TVD -ss). In this well the formation unconformably overlies the Cretaceous Matanuska Formation, a thick sequence of marine shale that contains an abundance of inocerarnus fragments. The West Foreland was also penetrated in the Cosmopolitan State #1 and the Starichkof State Unit #1 and was lithologicaily comparable to the section in the Starichkof State #1. The West Foreland Formation is a basin wide, regionally recognized geological formation of Paleocene to Eocene age and represents the earliest phase of post -Mesozoic sedimentation in the basin. In the Cosmopolitan area the West Foreland consists of thick beds of volcanic ash fall tuffs, tuffaceous claystones, tuffaceous siltstones and clay matrix supported sandstones. This lithoiogic assemblage is an ideal lower confining zone as it has no effective permeability and covers much of the Cook Inlet Basin. Exhibit E-1 Exhibit E-2 14 23 IT i5 24 25 9 Structure Map on Hemlock C.I. =100 feet Exhibit E-3 Stancnhor state Wirt i c,,3 19 20 2 2 1 r' x . r c 30 7U4 1 BI Crept Plbne Cos State 2 t l Nan n 1 L1 nqar1Hase�(t Z011S SI Pol r IA h , ti C ^�. 1 6= 32,or r G BIc,�Crest .. �` 34 ! Cosmo ti 8.1 O 3 i b 5 r: 3 7. 700' ; DW j 7 0 wQo ro 9 10 Z 15 17 16 5 15VV ATTACHMENT E 1500 300 0 avlty It Mme ogratie Parameters Surface Looadon t4A083 Alaska State Plane. Zone 04. US Feet Ausoaaneous MOON: DOOM 2013 olp� 72.866• Date. 2744ay-2014 Lal: it 6141 26.36 wortfuny21g44162.011701 rA1d Cam -16004• Owl OWN I TVD Ret RR81146ft above MSL1 AtaODeC. MAW FS: 66067.644nT Wavily FS, 1001.207rn¢1 {9.80686 Bas4101 Lon W 16148 WAS Eastlnq: Y3W740.6878 us Scale Fact 1.00004421 Plan. DWNt WPOSA 071714 AM Two 0MDDTvD 0 _ _ D DC ` �nC' 242 ' i az 1320 ft Surface Tick Marks _ D W<ve7l1(YC14ea. 120 MD 12C I'Vu 0 00' nc. 242 ' a2 C vsec `c 2144162 D61n.S '_ ' 3)6740 57f1�S Conducto° True : VO 50Q = vs Grid rc 24; a2 Mag .set 'r 2744162 010011-S F 3ibe1a057nu5 j KOP :cones"teat �rtti 601 MD, BeSOI T V. 0 00 " �nCi 242 17 u \•Vii �f 0 vsK -> Tot Corr (MT 16.552') surface ca61n0 Meg Dec (16 552') 3121 MD 2700 TvC 5W MD 1506 TVD Grid Conn -1.560') —3919' 296 •aee 20217 • a2 9'9 "x424 '7 az 35 -1K ' N 21468 57f1�,S E 1307576 44%S '2: 'sac Top of Aquifer Exemption (3000 TVD) Base of Confining Zone (3525 TVD) Upper Tyonek 13525 TVD) 3 4500 i 10 TDS 11 J y 6D�Q T ';1000 737 7379 .'C; 6t{iC TvD 39 19 ` -,c. 242 -7 az ae6� .ae LWR Tyonek "B" (6689 TVD) Bottom of Hole 750 9959 MD 6000 TVD 39 19' we, 247 17' az 551' vsec ear Stanchkof (7976 TVD) Bottom of r-loie Hemlock (6390 TVD fes. 1320 ft Well TD Tick Marks 900 TOP Lower Confining zone (9042 TVD) DW#1 WP06.4 077714 ADI Wa8 TD;eauny Depart 11310 MD 9050 Tv�'' 3919' tut 202 17 a7 -6473 vote •6000 4500 3000 1500 0 - -.. .-.... - ..n. _...... - - ..-I C I4a It=.I - F14:nt sale - Lrf ?1. s5rt}i 744.4. '2M -" .8006 54W 4634 +hes moo -3000 24M .'&M :700 41411 ,1 am 120D 1 Train olNarsuuct:ra 0 MD 0 7 vC, 120 MO 12O - v' 'j 0c, "Cl 242 1: at \ DX nc 247 s: N=.192E N 2144-F,. '9n S E 130974 VD e.L r �g OOC•=eei24<'7 a, 96nom of nae 50ace '-"r,;; 9959 MD 8000 rv( 312 MD V OC 39 , y .4 19 ns s - T E = sr7e: rr 7v"=='<'t• \\FOCI t.. \ Shy V;: '506' V:. avcto^ F 1 42 a µ 500 "VO N. 4 F°4'_ 41'7'a: Bottom of Hole E 1308740 57t1u5 T'JS 'Ov'.0 AV 1320 fi Surface Tick Marks 1 r a ,•4 My+rOS� T•v: 35 ' c C. 242 17 a2 ,..32.4 -4..5839 i` 1320 ft Wei TD Tick Marks DW#1 WP06 4 071714 ADt 1260 WO 0 1100 u 012)0 k 1.01 tr 30Z AM -4200 a+ao Surface Loaatlon Naorg 2144162087 Ed" 1308740.567 'aeoule N "51 2536 L"4uW W 151 48 15 45 VSK Aamvot 62173 Tallies De6o ww" 4irld Cooed Leas) Cooed room Name Shape 0111eroron e Lwypatde Hordlm0 Ev" TVD VSK •3+Si•> El"AM-1 132D It Surface Tick Mrks Racier" 2840.00 v 2640 OD N 59 Si 2758 W 151 46 7 62 214440700 168' . - 00 145 OU 000 Aw 18 -114 80 Bottom of Plate C-00 100 00 dsm"ie, N 50 51 175 IV 151 49 4485 214,92100 ' 6YAC 00 833 00 561666 .2814 O6 swi 94 1320 R Wok TO res., Mams Ree fVft 2640.004264000 N 59505693 WV 151 49 5644 214165009 .,cs,;1180 875000 am 1O 309978-! 587253 &ao k s ds" Few 11010 INCL TON{� 11 1 141+MfH r.ot coo 4 011 2411 '7 'i OC ... '• a di. 920OC00 242 17 ^20 OD : O4;»m. 000 500 00 00 242 '7 500 00 _;111. ' v. ' e + o;. 0 00 oLltedl 600 57 0 00 242 17 600 57 . Ix ' 4;: ^ iJ "41 000 186032 3914 241 11' ': "..4k+ 69 .In 21 342 5b 37 P, 4DO awv 3121 25 39 19 242 1 7 2700 o0 ' 295 91 ?9'±2 1250 65 0 DD AQU61 Eaempeon 3506 32 39 19 242 17 3000 ou 540 SZ 11 3r 147116 0 DO of CoMnirg tans 410569 3919 242 17 3525 00 ! 968 53 '' 1 ^0 1855 000 Upw Ty„rk 416569 3919 242 17 352500 "M 53 , " 1C 185: w 0 DO I, 10000 7370 02 39 19 242 17 6000 oc 3&783 31 2053 rte 3640 16 0 OD wRTyaruk'B' 8526.03 3b 19 242 ±7 8689{x, 471 "6 ?39' 3E 426' 16 000 Wee 51 33 19 24, ,' '974 0( 467 M 2lsar ti 5004 * 000 bottorn of Hole 995& 46 Ne 19 2411 6000 OC %'6 0 a 1 a 2L 50112 7v 000 10462 67 36 111 242 .: 3390 0E 5V34 $1 258s 6`3 S:sti3 40 000 TOP Lava C619" torr 113D3 90 36 18 242 17 W42 O0 '0406 46 •321 -7 54!1 349 000 416 TO tossav Demi 51314 22 39 i9 242.17 5050 Cc -3473 OC -3213 8' 5639 26 0 00 Base of Confining Zone (3525 TVD) Upper Tyonek 13525 TVD) 3 4500 i 10 TDS 11 J y 6D�Q T ';1000 737 7379 .'C; 6t{iC TvD 39 19 ` -,c. 242 -7 az ae6� .ae LWR Tyonek "B" (6689 TVD) Bottom of Hole 750 9959 MD 6000 TVD 39 19' we, 247 17' az 551' vsec ear Stanchkof (7976 TVD) Bottom of r-loie Hemlock (6390 TVD fes. 1320 ft Well TD Tick Marks 900 TOP Lower Confining zone (9042 TVD) DW#1 WP06.4 077714 ADI Wa8 TD;eauny Depart 11310 MD 9050 Tv�'' 3919' tut 202 17 a7 -6473 vote •6000 4500 3000 1500 0 - -.. .-.... - ..n. _...... - - ..-I C I4a It=.I - F14:nt sale - Lrf ?1. s5rt}i 744.4. '2M -" .8006 54W 4634 +hes moo -3000 24M .'&M :700 41411 ,1 am 120D 1 Train olNarsuuct:ra 0 MD 0 7 vC, 120 MO 12O - v' 'j 0c, "Cl 242 1: at \ DX nc 247 s: N=.192E N 2144-F,. '9n S E 130974 VD e.L r �g OOC•=eei24<'7 a, 96nom of nae 50ace '-"r,;; 9959 MD 8000 rv( 312 MD V OC 39 , y .4 19 ns s - T E = sr7e: rr 7v"=='<'t• \\FOCI t.. \ Shy V;: '506' V:. avcto^ F 1 42 a µ 500 "VO N. 4 F°4'_ 41'7'a: Bottom of Hole E 1308740 57t1u5 T'JS 'Ov'.0 AV 1320 fi Surface Tick Marks 1 r a ,•4 My+rOS� T•v: 35 ' c C. 242 17 a2 ,..32.4 -4..5839 i` 1320 ft Wei TD Tick Marks DW#1 WP06 4 071714 ADt 1260 WO 0 1100 u 012)0 k 1.01 tr 30Z AM -4200 a+ao Surface Loaatlon Naorg 2144162087 Ed" 1308740.567 'aeoule N "51 2536 L"4uW W 151 48 15 45 VSK Aamvot 62173 Tallies De6o ww" 4irld Cooed Leas) Cooed room Name Shape 0111eroron e Lwypatde Hordlm0 Ev" TVD VSK •3+Si•> El"AM-1 132D It Surface Tick Mrks Racier" 2840.00 v 2640 OD N 59 Si 2758 W 151 46 7 62 214440700 168' . - 00 145 OU 000 Aw 18 -114 80 Bottom of Plate C-00 100 00 dsm"ie, N 50 51 175 IV 151 49 4485 214,92100 ' 6YAC 00 833 00 561666 .2814 O6 swi 94 1320 R Wok TO res., Mams Ree fVft 2640.004264000 N 59505693 WV 151 49 5644 214165009 .,cs,;1180 875000 am 1O 309978-! 587253 &ao k s ds" Few 11010 INCL TON{� 11 1 141+MfH r.ot coo 4 011 2411 '7 'i OC ... '• a di. 920OC00 242 17 ^20 OD : O4;»m. 000 500 00 00 242 '7 500 00 _;111. ' v. ' e + o;. 0 00 oLltedl 600 57 0 00 242 17 600 57 . Ix ' 4;: ^ iJ "41 000 186032 3914 241 11' ': "..4k+ 69 .In 21 342 5b 37 P, 4DO awv 3121 25 39 19 242 1 7 2700 o0 ' 295 91 ?9'±2 1250 65 0 DD AQU61 Eaempeon 3506 32 39 19 242 17 3000 ou 540 SZ 11 3r 147116 0 DO of CoMnirg tans 410569 3919 242 17 3525 00 ! 968 53 '' 1 ^0 1855 000 Upw Ty„rk 416569 3919 242 17 352500 "M 53 , " 1C 185: w 0 DO I, 10000 7370 02 39 19 242 17 6000 oc 3&783 31 2053 rte 3640 16 0 OD wRTyaruk'B' 8526.03 3b 19 242 ±7 8689{x, 471 "6 ?39' 3E 426' 16 000 Wee 51 33 19 24, ,' '974 0( 467 M 2lsar ti 5004 * 000 bottorn of Hole 995& 46 Ne 19 2411 6000 OC %'6 0 a 1 a 2L 50112 7v 000 10462 67 36 111 242 .: 3390 0E 5V34 $1 258s 6`3 S:sti3 40 000 TOP Lava C619" torr 113D3 90 36 18 242 17 W42 O0 '0406 46 •321 -7 54!1 349 000 416 TO tossav Demi 51314 22 39 i9 242.17 5050 Cc -3473 OC -3213 8' 5639 26 0 00 &ao k s ds" Few 11010 INCL TON{� 11 1 141+MfH r.ot coo 4 011 2411 '7 'i OC ... '• a di. 920OC00 242 17 ^20 OD : O4;»m. 000 500 00 00 242 '7 500 00 _;111. ' v. ' e + o;. 0 00 oLltedl 600 57 0 00 242 17 600 57 . Ix ' 4;: ^ iJ "41 000 186032 3914 241 11' ': "..4k+ 69 .In 21 342 5b 37 P, 4DO awv 3121 25 39 19 242 1 7 2700 o0 ' 295 91 ?9'±2 1250 65 0 DD AQU61 Eaempeon 3506 32 39 19 242 17 3000 ou 540 SZ 11 3r 147116 0 DO of CoMnirg tans 410569 3919 242 17 3525 00 ! 968 53 '' 1 ^0 1855 000 Upw Ty„rk 416569 3919 242 17 352500 "M 53 , " 1C 185: w 0 DO I, 10000 7370 02 39 19 242 17 6000 oc 3&783 31 2053 rte 3640 16 0 OD wRTyaruk'B' 8526.03 3b 19 242 ±7 8689{x, 471 "6 ?39' 3E 426' 16 000 Wee 51 33 19 24, ,' '974 0( 467 M 2lsar ti 5004 * 000 bottorn of Hole 995& 46 Ne 19 2411 6000 OC %'6 0 a 1 a 2L 50112 7v 000 10462 67 36 111 242 .: 3390 0E 5V34 $1 258s 6`3 S:sti3 40 000 TOP Lava C619" torr 113D3 90 36 18 242 17 W42 O0 '0406 46 •321 -7 54!1 349 000 416 TO tossav Demi 51314 22 39 i9 242.17 5050 Cc -3473 OC -3213 8' 5639 26 0 00 •� e field: DW# 2 DW# 2 Kenai Exploration Hansen Pad erawty a Mag"Ve Paramours Surface Location NAD27 Alaska State Plano, Zone 04. US Feet Mtseaaarmous MOON, BOOM 2013 ft, 72666" oats, 274"Y•20m Lat N 5661 27.sa NoMmAt 21"4071tU0 011e Conv .1.6614• 6101 DM TW Rot RK8It46n above M&Lr t M39DOC: 16.662• F8. 66017.844n't Gravay FS 100t.207m9119.0466 BaseOJ Lon' W 16146 7.62 6aatr/0, 166717Rus Same Fact 0WUll1 Plan DOM WPWA 071714 ADI 3000 i o d500 Top of Aquifer Exemption (3000 TVD) Upper Tyonek (3525 TVD) Base of Confining Zone (3525 TVD) Svrtmet c9mg 3121 MD 2700 FVC 39t9'met 24217'aZ Eoc 1246 v6a4 '560 MD ' SO® TW) 1.2)Z383C3WILISE18%554ocr1,.S 30'?'�nc�,'47'"'u :22 .se er" nU SQ" • 1 07' 5437793 &106-M 1200 am 41000 34W 4601: 424-0 .3", -mm 441law 1200 14L 6W -XG 1664 590 MD 500 TVD 1320 h Surface Tick Marks Iwo 0DO, - 24:'7'a2 N."91 E..1 t 5 N <,'144407 001K,S F .h"' "Ofr'S2D0 WD \ WD 0 d 'Wp y ( 3 ,2 t lax i w 05 rvD ? .7wo i i 4 NOW .2a0 +600 62173 Laos Cees 1 H-1Mti-t 1.461 0 MD 0 TVD 0 1320 ft Surface Tick Marks - v-- ---- — - - 0 09 " -,1242 „ a: 0 Sac Ouut 000 True 0lxrisirucbuta 120 MD 120 rv0 0 00 • nc 1 242 1 7 aZ 1500 ° .�. a r% TF \�1 Gntl Mag fUe 7!2 TotCorr (MT KOP iromp.140^ 591 MC 4iCt "Vrti; 000" �u2421 ' 0vsec :..sec N 2144x07 00AL S E 156` = 7 00nUS cona--0. ,�5"vt'', MC 100 2vD 02 000° of 241'7 sz 0 „sec N 2144407 00nvs E 2087.7 09.9US 000 900 Mag Qec1Gnd 1100 .00 a 0 000 Con, (-1 000 3000 i o d500 Top of Aquifer Exemption (3000 TVD) Upper Tyonek (3525 TVD) Base of Confining Zone (3525 TVD) Svrtmet c9mg 3121 MD 2700 FVC 39t9'met 24217'aZ Eoc 1246 v6a4 '560 MD ' SO® TW) 1.2)Z383C3WILISE18%554ocr1,.S 30'?'�nc�,'47'"'u :22 .se er" nU SQ" • 1 07' 5437793 &106-M 1200 am 41000 34W 4601: 424-0 .3", -mm 441law 1200 14L 6W -XG 1664 590 MD 500 TVD 1320 h Surface Tick Marks Iwo 0DO, - 24:'7'a2 N."91 E..1 t 5 N <,'144407 001K,S F .h"' "Ofr'S2D0 WD \ WD 0 d 'Wp y ( 3 ,2 t lax i w 05 rvD ? .7wo i i 4 NOW .2a0 +600 62173 Laos Cees 1 H-1Mti-t 1.461 '5962 22 -562264 Ouut 000 ow 000 400 000 000 900 1100 .00 a 0 000 000 000 000 0 GD Vorenole: 2145030 ON welt: Field: 1iStructure: -- -' -- ` .. - ""--- ...! 2 DW# _�k_... DW# 2 Kenai Exploration Hansen Pad�� Gravity i Magnetic Patxnalsrs Suitaca Location NAD27 Zile State Plane. Zona 04, us feel 111.111141 __ Ef+)AVI.1 — OLS Model- S6GM 2017 OSP 72.667' MagDae: 76.6!3' F8: 6608b.692nT Dale: 27J4aY,2014 0ravrty FS: 1001,7D6Rt�t 19.69666 Bashi gat N 6961 33.76 Lon. W 16148 4.N Orad sem 1,6578, NortMnO 214"30.13"YAM.464ft E-unw Slot DWa 2 TW Rat UrAnown1146a above MSLI E.V—, "Y1 V5ec Scale fact 1,00002477 Plan IDWX2 WPO2 071714 am Rect"'e 0 11 551, 33 76 EJV fn, Saw - 1 7W44704%14077iai '58091, 46 1320 ft Surface Tick Mark DW#2 :7 UCi Te -1:, .1900 32550 2600 1950 1300 -650 0 650 1300 1950 1500 3000 V] r 4500 W N 4= Q 6000 7500 f 9000 0 MD 0 TvD Contlucto 0 00' ;nci 334 16 " az 500 MD 500 TVD 0 vsec 000' me 334 16 ' ai N 2145030 9411US E 168696 46aUS D vsec dillKtiuMial N 2145030 9<MUS E t68895 46MUS 120 MC 121 ' VJ 0 00 ' :nci 334 16 • az i 0 vbec N 2145030 941IUS E 168896 4611US KOP tcon puled) \i EOC 1033 MD 1033 TVD 2013 MD 1938 TVD 0 00' 001334 18' az 39 19'x101334 16' az O vsee 322 vbec N 2145030 94ftuS E 168696 46fa35 N 2145324 68f1US E 168763 964US Surface Casmil 2996 MD 2700 TVD x-39 191 incl 334 16' az 943 rsvc N 2145a9166ffuS E 16856858ttvS Top of Aquifer Exemption (3000 TVD) Upper Tyonek (3525 TVD) Base of Confining Zone (3525 TVD) 68,10010 \\l 7253 MD 5000 'JL' 3919' nc,334 16' az \ 3634 .500 L _WR Tyonek "B" (6689 TVD) p� 1320 ft Well TD Tick Mark DW#2 8006rn C7 hc. 11168 MO y05O 7 v 39 19' -,01334 1 az DW#2 WP02 071714 adt N'-'s`a-262 N 21506'0 Wft .S E 166360 OOMUS 1 BHL DW#2 \\\� TOS -10000 3 7253 M 6000 TVD 39 19' nc, 334 16' az \\\\ N=3.071= -153s t y P+ Surface W8lLn� 2996 VD. I: "VC 39 19 nn 334 16 or T,a1n Ns1285 E --36s 0 MJ O f vO N 2145890 66f1US E 168506 &"-S 0 00 - :nu 334 16, az N=438 L-46 EOC > 214''x,;30 9411US E 168896 46th; 2013 MD 1938 'VC 39 15' nc, 334 '6az N-726 E _..; N 2145324 66MijS E 16876', 46M�S 1711vN6;t.Cly a 12L M:, M IC A AZ N-4:,6 f =.r h; 4•; j; Sarc.;S E 168616 ft". KOr 1co+11p.:eJ 1033 MD 1,-3s 0 00-rc, 334 - az ^v>436E=4c `� 4.'450304<rtu5 E 1886Ve 4611„. V' U.Ct. 50' ME »c .."GS, tarictlkof (7976 TVD) 1320 ft Surface Tick Mark DW#2 emlock (8390 TVD) 1320 ft Well TD Tick Mark DW#2 BHL DW#2 :)P Lower Confning zone (9042 TVD) 80"la ,,, DVv#2 'WP02 071714 aot N 2150 IC 00h,,S E 166361 —114 0 1500 3000 4500 6000 7576 vertical Section till Azim 4: 334.164° Scaie - 1 616 498417696352fft3 Oitu n = 436 385N4S 47 61Mvv _..JL True Grid tag True North Tot Corr (M -T 18 553') I Mag Dec (16 553') Grid Cony (•1 558•) 7150 �D ! 5650 I 1 SWO ` 4850 N OW �yq$� P g00 � i No i 1 i 50 i Norti 2145030 ON Es" 168896464 Suffau Loasuen u111v0e N 5951 3378 Lonpaws w 131 48 444 _• JsecA:,nwtr, _�k_... - 334 MA TWOat Description Orid Coord 111.111141 __ Ef+)AVI.1 — OLS Loa! Caved Tar9m Norm Snaps Dar»n►wn Lalauoe Lbrgtuoe too V" E.V—, "Y1 V5ec 14f +V81.1 Ei+)A4M•1 1370 a Surface T4:4 Mad DW#2 Rect"'e 2840 00. 26W 00 11 551, 33 76 % 151 48 444 7145L3J 94 '58091, 46 4! OL :7 UCi 436'39 4762 1320 a Well TD TC'.Walk DW#2 Rectanye 2640 00. 2640 OO N 5u 52 28v2 N 1$146 $668 215NI1 3e 13838{', W 8750 jL 6120 W 8` 281953 OHL DW62 --'Ove 10000 of n"i h 5052 2802 vv 15146 %Oil .`1508/0 M16636,.00 071: 8751;tai 012020 159485 •251953 cd*.I outs! V C 111.111141 __ Ef+)AVI.1 — OLS 'no -in 000 000 334 16 J 0G . mi 430 36 41 b. ivdatrucru: a+ 120 OD 000 33416 20 Or, J30 43030 47", 000 500 00 0 OD 334 16 500 M : 00 43636 47 v, 000 OP(oomputa0) 1033.31 000 33416 10633' :OG 43636 47 jr, 000 071: 2D,3 06 30 11, 334 16 19384.1 322 2' 726 ate 82 80 40D Stbbmcalittg 298566 3919 33416 2700X 94:1' 128523 36336 DOD Top ofA*x*tE■empbon 33627: 3919 33416 =W ';7;770 156537 48497 000 upw Tyan" 406010 3519 3341t. 3525 OL 61572 ia1w61 6%5: 000 of Confimy Zone 41801c 39 t4 33416 3525 OL '51572 /SVD61 656S' 000 -50000 725342 39 19 334 16 8001 rA 3833 56 3706 76 ;M 87 000 WR Tyonek '8' 8400.44 3919 334 le 6619 O0 4358 36 4355 1 1 -851 73 000 SUV#d**t 9802 92 3919 334 16 797600 5244% 5156 75 2237 E. 000 Hanilook 10337 08 3919 334 16 0.380 Oc SSG,! 5466 5< 2385 53 000 TOP LAnei conbrot V tole 1117831 3919 334 16 9002 W 611367 593898 28; 6 (W 000 Of Mile 1118663 3919 334 16 9060 00 612020 54044 0 18lit W _. OW .�._.__-�._._...�. 1 ✓� I � 4SOD ti f OR I� a r� C 6000 i _ a ore Well: Field: Structure: DW# 2 DW# 2 Kenai Exploration Hansen Pad Gravity 8 Magnetic Parameters Urfa" Location NAD83 Alaska State Mena. zone 04. US Fact Miscellaneous Modal: 2OW 2013 Dip- 72.687' Data: 2746ay2014 Lot: N 6861 31.67 NonhmS• 21447616RUS GridCmt, 1.6667• Star- Data 2 TVD liter Ur*n"nl14M abovemki 1111690": 16.662• FS: 66088.02nT Gtavay F8: 1001.20r41nprr ISAW6 Basad) Lot: W 16148 1227 Emit: 130i820RUs Scala fact: 1.D0002608 Plan: DWa2 WP02071714 aA 0 _-------U20 ft Surface Tick Mark DVW2 Talo 0 MD 0 TV0 500 3oDo Hemlock (8390 TVD) Evr 81 Scs�e • � 63, 615279596173it 2998 Mf :700 TV_: dlve4itrucNtN G CD' mc; 334 t6 ` az ' 35 1g rres 3'ss 16 • a: :.ona.cta 120 MD 120 TVD C osec Conductor '�-•.�0 00 • ow 334 16' az "+ 2!44786 WftQS E 1 308920 00110 5 4550 3vOG 1250 Ze00 b5 300 ib 850 x300 1950 500 MD 500 Tv0 0 vs" v=436 E-48 r----------------------- _ •< 2 144 188 0013US E 1309920 OOhUS 17 0 00 - moi 334 15 ax n 2144788 OOWS E 1306920 00huS ''�� _ '950 1320 ft Weil TD Tick Mark D W#2 )00 7600 0 vsec 47 J4 N VAIS079 '?M -;S ; '30878" 120.04 000 N 2144786 ODits3S E 1306920 OORUS '2003 1300 MD 4756 00O KOP (coa�ftedi 5000D 6w Mc ass, 071 714 act \ SOD OD 7150 - 1033 MD 1033 TVD 650 5 ap<rt/aituttr'a 1 120 M^ +2u 'v' Bottom of . 01u 103331 .� 0 00' incl 334 18' ar 1033 3' x s t 89 MD 9050 r VD `Lie NOftT+ 000 0 vaac 0 1500 3000 4500 500(1 'SOC \ 39 19' mc1334 16' az Tat Corr Yi->T 16 553') in 2`• N 21447W0011US E 1308920ODhUS rte, EaC \ 2013 MD 1838 TVD 426« DWtl2 WP02 071714 adt N•5945 65 1411 0 � `• H 2!50385 t4ftu5 E 1306403 721!05 k4ag Dec l t 6 553' e300 39 19 ' mo 334 18' az Ven,cal Becton (ft) AziM = 334 164° Sc34e = 1 665 335377730693(x!) Origm = 436 37WS 47 582E. -V41 94311 Grid uonv (•1 560') 3W 42 000 322 rsac 54rlsco cauno 338773 3919 �— 3000 3L 1 $7 70 • N 2145079 73'hUS £ 1308787 53ftUS 2996 MO 2700 TVD SMUS 11 Aeo Local" 000 N 59 51 31 S7 .wrpuwv W 651 48 12 27 vSW Au,,w, Soso —3918'mct33416•u Tsrpm Dnsriptlon `•t BHLDW02 658 $4 Loaal caord .--- -- '�� 943 .sec Lmillo4 LoVItAt NimMmil raiii:,1i, TVG Am N1+d3(1 E(*#W(•) h 2145545 73f1US E 1308532 251US h 5851 33 78 i 4500 300 038 37 5 Top of Aquifer Exem\ ptlon (3000 TVD) N 59 W 28 02 yr 15' 40 5566 2' 508?GOO 1606L 00 875000 6120 23 51144 b9 •261894 BHL OW02 cstp4 100 00 danm , N 595Z 2802 6 151 4a 56 68 215061000 186380 00 ..r 705131/000 594411'e 7 4359 04 '85' 76 ODD 7253 MD 6DW T v r, 39 19' 16 az 980292 0550 Base of Confining Zone 0525 TVD) Upper Tyonek (3525 TVD) 797600 524458 •-1-1334 2737 91 ODD •.� 1033705 39 19 j 8390 GD N j .9900 S 7500 TDS- WO00 7253 MD SDGO TVC 34 334 16 az 3634 'sec $'-face case,9 Hemlock (8390 TVD) i I di l e j 3230 2998 Mf :700 TV_: Gftir.1 Peims ' 35 1g rres 3'ss 16 • a: :.ona.cta o Y=!285 E=-363 N 2145645 734US E 1308532 25hUS 500 MC 500 TY0 _ 30' mc, 334 16. 82 w 2600 AM v=436 E-48 BHL DWlt2 •< 2 144 188 0013US E 1309920 OOhUS 17 EOC 2013 MD 1938 TVC ''�� _ '950 19'4' W,33416'az )00 OX N-726 E-9; 9; 47 J4 N VAIS079 '?M -;S ; '30878" 120.04 000 33416 '2003 1300 MD 4756 00O 3s4 Iti a7 5000D 6w Mc ass, 071 714 act -44436 E=48 SOD OD ti rsda78E OOr,,,=. r 308924 001605 � 43631 650 5 ap<rt/aituttr'a 1 120 M^ +2u 'v' • 103331 LWR Tyonek "B" (6889 TVD) I'rO, ,+0 334 1f 46 0 N-436 'e_-8 N 2 44 76t junVS E 130892L liOtR 1 w � 650 Starichkof (7976 TVD; 1320 ft Surface T rcK marK DWu2 Hemlock (8390 TVD) Gftir.1 Peims 1320 ft Well TD Tick Mark DW#2 cimal rim p WCL AM NO BHL DWlt2 t l sono TOP Lower Confining zone (9042 TVD) OOD T1 ue )00 OX 4-16 3- 47 J4 'Grta 120.04 000 33416 '2003 accom of rta•e 'v./D'�2WPO2 43x43' 4756 00O comilkwor 5000D 6w Mc ass, 071 714 act fi SOD OD LK, 43631 tiN' SC385 41,..5 E 306403 2" _mag 103331 .� 334 16 1033 3' x 4363 `Lie NOftT+ 000 r 0 1500 3000 4500 500(1 'SOC 334'.E Tat Corr Yi->T 16 553') in 2`• -Xs Y' 426« 400 swrisw Gs1r1p k4ag Dec l t 6 553' 3918 3,1416 Ven,cal Becton (ft) AziM = 334 164° Sc34e = 1 665 335377730693(x!) Origm = 436 37WS 47 582E. -V41 94311 Grid uonv (•1 560') 3W 42 000 Top of Aquila, EaempuoR 338773 3919 334 16 3000 3L 1 $7 70 - 11 Aeo Local" 000 Notary 2144786 Easarip 13W2D .au.44 N 59 51 31 S7 .wrpuwv W 651 48 12 27 vSW Au,,w, .419 334 164 1 Tsrpm Dnsriptlon Grre cooro 861 56 658 $4 Loaal caord Trge Nam4 Snaye Diirmm + Lmillo4 LoVItAt NimMmil raiii:,1i, TVG Am N1+d3(1 E(*#W(•) 12.201 SUrtWe r4:a MWk DA1a2 Reeurt9w 264600 r 2640 OD h 5851 33 78 Jr t5; 46 444 2'45030 94 ,raa5t, 4G 4500 300 038 37 4756 13120 4 Wei TO Tc. Mara DWa2 Ractargm 284000 > 264U 00 N 59 W 28 02 yr 15' 40 5566 2' 508?GOO 1606L 00 875000 6120 23 51144 b9 •261894 BHL OW02 cstp4 100 00 danm , N 595Z 2802 6 151 4a 56 68 215061000 186380 00 0750 W 612023 � 594411'e .261994 Gftir.1 Peims cimal rim p WCL AM NO VSECl+Y t l 000 OOD 334 16 )00 OX 4-16 3- 47 J4 iwtsbucwral 120.04 000 33416 '2003 i?3C 43x43' 4756 00O comilkwor 5000D 000 334 16 SOD OD LK, 43631 4758 0.00 OP (carwit,d) 103331 um. 334 16 1033 3' x 4363 4750 000 OC 20,300 19x9 334'.E '93e 43 in 2`• -Xs Y' 426« 400 swrisw Gs1r1p 299566 3918 3,1416 27W a., 94311 126521 3W 42 000 Top of Aquila, EaempuoR 338773 3919 334 16 3000 3L 1 $7 70 505 3S 47001 000 81804 of ctitr4 my taro 4066 10 .419 334 t6 3525 OL 161 S 72 861 56 658 $4 ODD UPPM 1711,01,101, 4060 to 39 19 334 i6 3525 X, 161572 two 59 55654 000 3>10000 7253 42 39 1 S 33416 8ODO Oc 363356 3713✓ 75 535 90 0 G0 YVR Trawl, •' 84OD 44 3919 334 16 6889 OC 45,5836 4359 04 '85' 76 ODD Star~ 980292 39 i9 334 18 797600 524458 51556 73 2737 91 ODD 1033705 39 19 T.M 18 8390 GD 5582, 1 546! 51. 235507 aDO TOP Lower eartknow tone 1117831 3919 334 16 1042 W 61;367 593E 96 26'872 000 90130111 of two 11688 63 3912 33418 5,060 OG 6120 20 _ _ 1044 03 •2019 56 �. _ DOD ri06' to s 22 6112 2% 34 3 82 LIE m )2 Sks' Hemlock Conglomerate Structure Map Structural Control is from well formation tops, 3D Seismic and high-resolution Migrated 2D seismic lines from Geo -Hazard Survey 13 24 1125 1 :6 1 4 6 5 7 4 BiueOrest kA 113 4f 9 00 Planned Water Disposal A Well - bhl A -1 5VV 14 / I x W a M 0 R3 L 0 o O n) Aln RT ODW I_ O 4. F+ tLS O �`` o � 41 a cv Q. • — L oor c i 4-0 T cl • W L cu y� T �- E � -a o c a f0 Q} � o o Q CL0 t � f 14 t m m E L O hU v cuMY1UI 3 C u .0 0 � E o L � 4-0 v) V G1 � � M L V i2 E DO W O T O m O Y `CL _ L • V) i U L ,4W on c`9-- . ;usnae uw �J40 W ro co L C1. c®r ,� t'y _v o© W r r`.oiHvx 69 � h 'i t �c,s�:=u nCt3 I ©`s 04 cv i Q� 401 o J i i i c r M i �J40 W ro co L C1. c®r ,� t'y O 0. O L CL O dw cu .w c m a CL O E LM O V E O L LL i O V cn N 0 O LmV a� Lilt f2 AE -data entry for BlueCrest D1,NP1.xlsm Field J Entry Operator BlueCrest Alaska Operating LLC Operator Street Address 3301 "C" Street, Suite 202 Operator City Anchorage Operator State A!aska Operator Zip Coae 99503 Business Type Focus: acquisition, exploration, and development of o , and gas resources w+tnin the united States Permit Type Injection Well ID No. DW #1 Area Permit No. Well Class i injection Activity ,Materiais p;annea to De injected are non -hazardous oJieio dr,n.ng and production wastes from the drilling and production activities, which could include produced onne, mud, cuttings, rain water, camp generated, wash water, test fluids cooling water, etc among other waste streams Injection Activity Category state Alaska County Kenai Peninsula Borough Tribe Unknown AE Location (TRS) ASP Zone 4, Seward Meridian DW #1: Surface hole location: Sec 02 4s 15w Bottom Hole Location: Sec 10 4s 15w AE Location (Degrees Latitude) using NAD83 NAD 83 DW # 1: Surface hole ocation: 59.512538 Bottom hole Location: 59.50556 AE Location (Degrees Longitude) using NAD 83 DW NAD83 #1: Surface 1-iole location 151.481545 Bottcr, rio'e Locat.o=r 15 1. 5010751 AE Location Notes DW 91 Surface Location: NE 1/4, SE 1/4, SW 1/4 of Sec 02 4s 15w Bottom Hole Location: NW 1/4 Sec 11, N 1/2 Sec 10, S 1/2 Sec 3 in 4s 15w AE Area 1920 AE Area Units acres AE Delineation Notes Aquifer Exemption area is downdip of the C05m0P0!Jan f,eld offshore and encompassess most of the east side of that structure out is OFFSHORE. Aquifer Exemption Depth 3000 - 6500 True Vertical Depth (TVD)(a "no USDVV" aeterminatiorl ,s requested below 6500 Aquifer Exemption Depth Units feet injection Zone various zones in Upper and Lower TyoiieK and upper r ienlock Upper Confining Zo ae ITyoneK 2-/'00-3475' TVD Lower Confining Zone i HemiaCK 9142 7V D Formation Thickness 3500' TVD Lithology Upper Confining zone: shale, claystones, coal teas i -ower Confin ng Zone: ash fall tuffs, tuffaceious claystones and siltstones, and clay matrix supported sanastones Water quality ;>4500 nig/I below 3000 , > 10000 mg i oelow 6500"v D Water quality (Data sources ;Flog caicu,ations Anchor Pt t, 1, Cosinoho ,tan State til, rsansen =r , Produced water analysis ;Ninilchik 01 Injectate Characteristics Materials planned to be injected are non -hazardous o:,'-e;d Carhkng Jnci production wastes from the drilling and production activities, which cou,a Include procioced brine, mud, cuttings, rain water, camp generated, wash water, test fluids, coolifiv water, etc among other !waste streams Program Revision Type Exemption Review Decision Approval Date Criteria Cited Comments/ Notes Date Added Source AE -data entry for BlueCrest DVVP2.xlsm Field Entry Operator BlueCrest Alaska Operating LLC Operator Street Address 3301 "C" Street, Suite 202 Operator City Anchorage Operator State Alaska Operator Zip Code 99503 Business Type Focus: acquisition, exploration, and development of oil and gas resources within the united States Permit Type injection Well ID No. i DW #2 Area Permit No. Well Class 1 Injection Activity Materials planned to be injected are non -hazardous oilfield drilling and production wastes from the drilling and production activities, which could include produced brine, mud, cuttings, rain water, camp generated, wash water, test fluids coolrn water, etc among other waste streams Injection Activity Category State Alaska County Tribe Kenai Peninsula Borough Unknown AE Location (TRS) ASP Zone 4, Seward Meridian DW #2: Surface hole location: Sec 02 4s 15w Bottom Hole Location Sec 35 3s 15,v AE Location (Degrees Latitude) using NAD83 AE Location (Degrees Longitude; using NAD83 NAD 83 DW #2, Surface hole location: 59.513157 Bottorn Hole Location 59.522584' NAD 83 DW #2: Surface hole location: 151.481227 Bottom Hole Locat,on 151.990452 AE Location Notes AE Area DW #2 Surface Location: NE 1/4, SE 1/4, SW 1/4 of Sec 02 4s 15w Bottom Hole Location: W 1/2 Sec 35, E 112 Sec 34 of 03s 15w. 1920 AE Area Units acres AE Delineation Notes Aquifer Exemption Depth Aquifer Exemption area is downdip of the Cosmopoiitan f eid offsnor e and encompassess most of the east side of that structure but is OFFSHORE. 3000 - 6500 True Vertical Depth (TVD)ja "no USDW" rceterminat,orr .s requested below 6500 Aquifer Exemption Depth Units feet Injection Zone Upper Confining Zone various zones ,n Upper and Lower TyurieK arld upper r,emock Tyonek 2700-3475' TVD Lower Confining Zone Hen-ilock 91427VD Formation Thickness 3500' TVD Lithology Upper Confining zone: shale, claystones, coal beds ower Confin;nq,. Zone: ash fall tuffs, tuffaceiaus claystones and siltstones, and clay matrix supported sandstanes Water Quality Water Quality (Data Source) >4500 mg/I below 3000` , > 1-0000 rng/i Ueiovv 6500'TvD Elog calculations Anchor Pt til, Cosmopoi tan State IN 1, r-iansen ol, Produced water analysis Nindchik til Injectate Characteristics Materials planned to be injected are non -hazardous o;;l,e,d drill ng and production wastes from the drilling and production activities, which couid inciude pr0ti0ced brine, mud, cuttings., ran water, camp generated, wash water, test hinds, coni fie water, etc among other waste streams Program Revision Type Exemption Review Decision i Approval Date Criteria Cited Comments/ Notes Date Added Source 1 a) E U m Q CO +- 8 F^ Q ., N V, ai 0 0 cD M ail m9ml, Starl'chkof State #1 K.B. = 68' Tipowl-khtM K I E14111 . i [) N s31., ; I t V IT V H 2. Si.S2i3r l• I r-ftn k r^ n. hLaJ: �P.M 4 0 ux s u L • ! 4mJ r4 7 J M V1 Orm CL In Proposed Confining Zone Base 2250 Projected Confiding Zone Base 4147' and •3350 TVDSS 4 � 6 -4 { z 4 0 ux s u L • ! 4mJ r4 7 J M V1 Orm CL In Proposed Confining Zone Base 2250 Projected Confiding Zone Base 4147' and •3350 TVDSS 4 � 6 { 4 0 ux s u L • ! 4mJ r4 7 J M V1 Orm CL In Proposed Confining Zone Base 2250 Projected Confiding Zone Base 4147' and •3350 TVDSS 4 � 6 Upper Tyonek 2280' -2212' TVDSS Upper Tyonek 4186' MD -3380' TVDSS t+ M d 1 ` i -x i-4 x t 171. � t i r i nntea rrom neuraview urrcarna Lower Tyonek 5662' 5594' TVDSS Starichkof 6749' -6681' v'DSS Hemlock 7148' -7080' TVDSS Top of Lower Confining Zone 7589' -7521' TVDSS Lower Tyonek 8526' MD -6744' TVDSS Starichkof 9929' -7831'TVDSS VDSS Hemlock 10462' MD -8245' TVDSS Top of Lower �.onfii ring Zone 11227' -8997' TVDSS Starl'chkof State #1 K. Be = V8' rC#Ili w lf% l.iJrlfiflmg Zune Base 2250 aaoi.al.l7.t. . •( i1 riYifitlM r"qi ���.. it-.�) .1� �Lt�R#+ �'AI'/sr�l►tt�.IIj 1 " i d l.iJrlfiflmg Zune Base 2250 Upper Ty{onek 228(' -2212' TVDss Upper Tyonek 4186' M D -3380' T DSS 411 t t rinted from NeuraView 07/26/14 Lower Tyonek 5662' 5594'ix'VDSS Starichkof 6749) -6681" ,rlvlmss Hemlock 71481 -7080Y TOSS IF 9 1 via 7 TOp of Lowet Approximate Lonfining Zone Stratigraphic Depth 7589 d n the Proposeu ' Reache i Wattet injection Well 7521 TVDSS a Lower Tyonek 8526' MD -6744' TOSS Starichkof 99291 -7831"r,VDSS Hemlock 104621 MD -8245' TVDSS I I
