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1 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. jQ - © 73 Well History File Identifier Organizing(done) wo-sided 1I 11111 I III II III ❑ Rescan Needed Il 111111111111111 F7AN DIGITAL DATA OVERSIZED (Scannable) Co or Items:vz/ ❑ Diskettes, No. ❑ Maps: Greyscale Items: ❑ Other, No/Type: o Other Items Scannable by a Large Scanner EOGs ❑ Poor Quality Originals: OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: C Maria Date: S I Li- /s/ vvIP Project Proofing ll IIIIIIIII1 IIIII BY: Maria> Date: /4 /s! 1° C Scanning Preparation Jo x 30 = 30O + = TOTAL PAGES 3 0 0 (Count does not include cover sheet) 1 BY: Maria Date: 5/5/1 /s! ', Production Scanning 11111 11111111111 Stage 1 Page Count from Scanned File: 301 (Count does include cover heet) Pa•e Count Matches Number in Scanning P eparation: YES NOmf3 BY: de Date:s J 6� /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. IIIIIIIIIIIIIII ReScanned 1111111111IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked III 111111 IJ111111 III o v o J I • . . • O O 0 E N N O O C •• U d - c O . . C _ a) E v a . aCi .a O Z / C a) C 2 • a) a 0 Q O •• G N •5 I E 5 0 • y v )n < .0 a x C9 0 m to 0 Q co a) w p Cl) X a N CO °t3v 03 yr > o N of Q a v ami a O C V) J V) y C Uco 17 cC c C co J J o in 0 E Q E _I n' N a U c 3 _c O W W E 2 o N• O al al as p O N a) H CO CO — E ,� Q7 co • �_ c N co w r . 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Q 0 0 0 0 0 0 0 0 0 0 0 o E y E v v 1 •• N N N N N .... ... N N N N N N N N N N N N {O 3 �- •'- • W N Z Ce U N N N N N N N CN et et Tr Q C .4. Nr -4 V • O W JINNI V a w d rn Z lo 00 0 0 N ft Q r+ lO CO CN1.0 O 0 J a co n. ° �' m 2 T O O O U) SII a) O " a E I M ✓ T 0 M 1. . J N M . I— J 0 LO � 0. J O a. W CO 5 0 To CO O N 2 0 CO W A o 0 Cl)/ co 0 I U) 0 N n ' 1 Q E Z D • U 1 E is Z . co CO CO Co 03 Co CO CO CO CO CO N CO CO Co Co Co CO CO Co0 CO Co Co CO CO Co Co CO Co CO Co Co CO CO CO Co CO Co O u n 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ! C � 4 4 0 Co CO Co CO Co 0 Co Co Co CO N @ CO CO CO CO t0 l0 I O O -u -u 0 6 5 5 0 0 6 5 5 5 0 0 5 5 0 5 5 o o E p O M > •• •• O O 0 0 0 0 0 0 N N N N N N N N N N N w ; o 0 o < < < ati :ii Q m m 2 `o `o m 1 11 40 U U -J Q I d Q Q z 1 II ��// 2 N 1 Li aci p ii O Z W Y o yO E N Wv, W 1 `° o Ti V V O E Z J m O Q 0 0 0) N. N J a C mw -0 E O co 2 0 U a v. . C � P , L N O la E w t M } `)1 E M en C E N Q O o V 10 cd •r J E 0. J W 0 O C� • N ra C c4p N e. a� E 1.4 c. c V CO m E Q 4O ! Ij I'll y c To cc a Q a ocry O Z Eo 2 g = E 1Z m o a 3 0 o o 7 N N G N N , ..40 , . . , re ,L.... , m.. p,.., E o. O p 1 m r o N C 1 N al c > n = •.a) a) D `° 0 O w c m as 0 w 0 U E a o a E a C7 O a • o a` ( 0 0 a 0 coy Guhl, Meredith D (DOA) From: Mary Ohren [maryohren@geothermalresourcegroup.com] Sent: Monday,April 14, 2014 12:02 PM To: Guhl, Meredith D (DOA); Schwartz, Guy L(DOA) Cc: 'R Mann' (raymann@rma-cg.com); 'K Mann' (kmmann@rma-cg.com) Subject: RE: AOGCC compliance requested materials to complete Abandonments Attachments: Garmin_image.jpg; GPSMAP_60CSx.jpg;Akutan_TG-2_Wellsite.pdf; Akutan_TG-4 _Wellsite.pdf Meredith, Previous submissions from the well completion reports are being updated based on the most recent mapping in the area.The location data was collected with a high accuracy GPS receiver with the skill of a professional mapping geologist. Previous location data for the two wells were gathered with lower quality GPS units with less skilled operators and errors came from uncertainty in the coordinate system in which the coordinates were collected and in conversion. The unit used to gather the location information for the two wells is the Garmin GPSMap 60Sx with a +/-3-5 m accuracy. An image is attached as well as a page from the user's manual regarding the accuracy. Revised plats are attached. Mary Mary Ohren Geoscientist Geothermal Resource Group, Inc. maryohren@geothermalresourcegroup.com 760-341-0186 Office 775-527-8963 Cell Mail: PO Box 11898, Palm Desert CA 92255 Deliveries: 75145 St.Charles Place,Suite B, Palm Desert CA 92211 The contents of this email message and any attachments are confidential and are intended solely for addressee.The information may also be legally privileged.This transmission is sent in trust,for the sole purpose of delivery to the intended recipient.If you have received this transmission in error,any use,reproduction or dissemination of this transmission is strictly prohibited.If you are not the intended recipient,please immediately notify the sender by reply and delete this message and its attachments,if any. 1 I- SPECIFICATIONS APPENDIX Altimeter: Accuracy:41-10 feet'.resolution:I U. 'Suhpet CO proper user cal Maiton . Specifications Power Source: Two 1.5 volt AA batteries.USH Data Cable, Physical I Volt DC Adapter Cable or up to 2l Volt DC Site: h.l"II x 2.4"W x 1.3"D extemal power %%eight:7.5 ounces(213 8)w/batteries insulted. Battery Life: Up to 18 hours(typical use)" Display:1.5"W x 2.2"H,256-color.high resolution. 'Alkaline Killer!.hex a ver tlucnr mimxmt of thcr 1.3j111./1 the transrcllcctive 1160 x 240 pixels)with backlighting. mmpenurc d onaa>Brawl.,u.c of.;rte t adhu ume.elecnorue Case: Rugged,hilly gasketed.water resistant.IEC-529,1PX7 mp.,anJ as ihlc lou "iemfiumty WY.soon'lil'c. Temp Range:5 to 1510(-15 to 70"C')' Accuracy 'Mctempcntn'raring of the OPSNAP6n(5x may exceed the usable range CPS: <10 meters(33 feet)95`1 iwpteal' Jt.oIne Niter IPC Some h,llfnfl can rupture al high ICIap:TJNfS' •St1'IC,1 tu Alcune)dcgatamq in Itatm:MINIS under Il,e I,S.Rd) unpmed Sciucn c:\raibhti ISA,Program r hen xveaed. Performance DG 15: 3-5 meters(10.16 feet 195°,typical` Receiver: W'AAS/LGNOS enabled 'WA;xs mems,in xonM1:wm"•dca Acquisition Times*: Velocity: 0.05 meter/sec steady state Appmx.I second(warm start) Approx.38 seconds(cold start) Interfaces:NAMEA01S3 version 2.3.and RS-232 and USB Approx.45 seconds(factory reset) for PC'interface lm er.anc10Ia,141.14nrcc.,aT1411h am opal ai„-n Data Storage Life Indefinite:no memory battery required Update Rate: ()second.continuous Map Storage: Dependant on the opacity of the Antenna: Built-in quad helix.remote antenna capability. microSDcard.' Compass: Accuracy:H-5degrees',resolution:I degree ''w'mwul"w""odds'cardc p+,ptom.krnoutm:Mn mmg bee,u m.e GPSMAP tSCSx Owner's Manual 4. • o c,anrfl/r GARMIN. w.__ GPSMAP' 60CSx � . - . GARMIN,`"/ G� 7.71,7 Trip & Waypoint `_: man Man< • -r I 12/0042093 100 :52 i N i_ I / / / / , -. 32 33 O Section Line Offsets: TG-2 2334 ft FEL i 259 ft FSL TG-2 location: / 444,078m E /� 6,000,884m N WGS84 zone 3N ' 531,227 ft E 56,218 ft N 38ft Elevation 7 ASPC NAD1927 zone 8 protracted section 32 te Township 69 South Range112 West Seward Meridian / / rj (--- // / ( r _ Akutan Geothermal Project Hot Springs Well #2 Wellsite Location N 500 250 0 500 1,000 API 50-295-20002-00-00 — Feet Applicant: 1:6,000 City of Akutan 3380 C Street, Suite 205 Date: 4/14/2014 Anchorage, AK 99503-3952 TG-4 location: 442,610m E 5,999,185m N WGS84 zone 3N 526,490 ft E 50,574 ft N 124ft Elevation ASPC NAD1927 zone 8 5 protracted section 7 Township 70 South Range112 West Seward Meridian Section Line Offsets: 1831 ft FEL 106 ft FNL lowO TG-4 60•m 120-m 7 8 Cr.Akutan Geothermal Project South Elbow Well #4 Wellsite Location N 500 250 0 500 1,000 API 50-295-20004-00 _ Feet Applicant: 1:6,000 City of Akutan 3380 C Street, Suite 205 Date: 4/14/2014 Guhl, Meredith D (DOA) From: Guhl, Meredith D (DOA) Sent: Friday, April 11, 2014 2:22 PM To: 'Mary Ohren'; Schwartz, Guy L (DOA) Cc: 'R Mann'(raymann@rma-cg.com); 'K Mann' (kmmann@rma-cg.com) Subject: RE: AOGCC compliance requested materials to complete Abandonments Mary, I reviewed the data submitted for Akutan PTD 210-071 and 210-073.The mudlog and .las files,digital copies of the inclination survey, along with the pressure and temperature data meet the requested requirements. However,the GPS coordinates provided were not converted correctly. Please review and correct the data.The two wells should be located in AK State Plane Zone 8, not Zone 10.Also the coordinates provided differ from the Well Completion reports previously submitted by as much as 100'. Please explain this discrepancy. Finally, because the GPS used to record the well locations is not survey-grade, please provide a description of the unit, including brand, model and +/- accuracy. Updated maps, along with the description of the GPS,and explanation of the discrepancy between the Well Completion report and the GPS may be submitted via email. Please submit the information by April 25, 2014. Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission meredith.guhl@alaska.gov Direct: (907) 793-1235 From: Mary Ohren [mailto:maryohren@geothermalresourcegroup.com] Sent: Tuesday, April 08, 2014 3:01 PM To: Guhl, Meredith D (DOA); Schwartz, Guy L(DOA) Cc: 'R Mann' (raymann@rma-cg.com); 'K Mann' (kmmann@rma-cg.com) Subject: AOGCC compliance requested materials to complete Abandonments Meredith, The requested materials for completing the abandonment of the two thermal gradient wells at Akutan were sent via UPS to you today,for arrival at your offices tomorrow by noon. Please let me know when they are received.Thank you. Mary Mary Ohren Geoscientist 1 Geothermal Resource Group, Inc. maryohren@geothermalresourcegroup.com 760-341-0186 Office 775-527-8963 Cell Mail: PO Box 11898, Palm Desert CA 92255 Deliveries: 75145 St.Charles Place,Suite B, Palm Desert CA 92211 The contents of this email message and any attachments are confidential and are intended solely for addressee.The information may also be legally privileged.This transmission is sent in trust,for the sole purpose of delivery to the intended recipient.If you have received this transmission in error,any use,reproduction or dissemination of this transmission is strictly prohibited.If you are not the intended recipient,please immediately notify the sender by reply and delete this message and its attachments,if any. 2 Office Project 11 April 2014 INPUT OUTPUT UTM,NAD83 State Plane, NAD27 03-168W to 162W,Meters 5008-Alaska 8,U.S.Feet Accuracies of conversions from NAD 83 to NAD 27 are typically 12 to 18 cm. SE-4/TG-4 1/1 NorthinglY: 5999185 Northing/Y: 50574.827 Easting/X: 442610 Easting/X: 526489.004 Convergence: -0 42 42.92026 Convergence: 0 06 00.43897 Scale Factor: 0.999640413 Scale Factor: 0.999900800 Grid Shift(U.S.ft.): X/Easting=-925640.6,Y/Northing=-19631751.3 Datum Shift(m.): Delta Lat.=96.664,Delta Lon=-128.858 Remark: Corpscon v6.0.1,U.S.Army Corps of Engineers _______ ---------'----"••-.-....,,-,'--^.../-",---- ------ -----------m----. iy ' TG-4 location: 442,610m E 5,999,185m N WGS84 zone 3N 5,163,923ft E 6 505-1- 4-/. g2 C - SP Z-p/J E 65 1,298,385ft N 5 Z(v y 8l , N tiAb 11- so 123ft Elevation ASPC NAD1927 zone 10 protracted section 7 } Township 70 South Range112 West 7 Seward Meridian j i �, \ Section Line Offsets: -� ,\ v 1831 ft FEL / ---�J 106 ft FNLr'� ' ‘) U TG-4 1 '--__7 i', S ., � ) °m r l 12 -----, _/\ - - v,, _ 7 - _ -- - // v 8 rti NrA, ,, - . i' / 7� ,,- -- \-/- \ / — / ) ------; Lha /----_ `�-- Akutan Geothermal Project South Elbow Well #4 Wellsite Location N 500 250 0 500 1,000 API 50-295-20004-00 R E.C.E IV E D NE - - Feet iiiimMIIMINN p1 Applicant: l-.r., 0 9 E:`; 1:6,000�. City of Akutan 3380 C Street, Suite 205 OtOG CC Date: 4/8/2014 TG-4 location: 442,610m E 5,999,185m N WGS84 zone 3N 5,163,923ft E 6 5 1,298,385ft N so 123ft Elevation ASPC NAD1927 zone 10 L-‘ section 7 Township 70 South Range112 West Seward Meridian Section Line Offsets: 1831 ft FEL 106 ft FNL *TG-4 12om 7 8 Akutan Geothermal Project South Elbow Well #4 Wellsite Location N 500 250 0 500 1,000 API 50-295-20004-00 RECEIVED — — — Feet Applicant: APR 0 9 2014 1:6,000 City of Akutan 3380 C Street, Suite 205 AOGCC Date. 4/8/2014 Directional Survey Report Geothermal Resource Group 1110 Well ID: AGP TG-4 Well Name: Hot Spring Bay Valley 4-Akutan Field: Hot Springs Bay V2 County: Aleutians East State: AK Country: United States Survey Meas. Coordinates Vertical Dog Leg Type Depth Inc. Azimuth TVD N-S E-W Closure Section Severity (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (deg/100) Well Bore: Original Well Bore Plane of Vertical Section: 0 TOTCC 103.0 2.00 TOTCC 208.0 0.75 TOTCC 301.0 2.50 TOTCC 403.0 2.50 TOTCC 503.0 2.00 TOTCC 600.0 2.00 TOTCC 703.0 4.00 TOTCC 803.0 2.50 TOTCC 903.0 0.50 TOTCC 1,001.0 4.00 TOTCC 1,103.0 2.25 TOTCC 1,203.0 1.25 TOTCC 1,303.0 1.00 TOTCC 1,403.0 0.50 TOTCC 1,500.0 2.00 Calculations using Minimum Curvature Method Printed: 14:17 26-Mar-14 RIMBase 7.0.2.114 Page: 1 of 1 AGP TG4 8/23/10 4:30 AM Survey Run#1 Time of Hours Since Time of Hours Since Depth Reading Last Circ Temperature Pressure Depth Reading Last Circ Temperature Pressure 0 4:29 35:59:00 60 14, 50 4:34 36:04:00 71 14 820 7:39 39:14:00 306 356 100 4:39 36:09:00 169 27 840 7:44 39:19:00 308 366 120 4:44 36:14:00 180 36 860 7:49 39:24:00 309 375 140 4:49 36:19:00 188 45 880 7:54 39:29:00 311 384 160 4:54 36:24:00 195 56 900 7:59 39:34:00 312 394 180 4:59 36:29:00 199 65 920 8:04 39:39:00 313 403 200 5:04 36:34:00 200 74 940 8:09 39:44:00 314 412 220 5:09 36:39:00 209 83 960 8:14 39:49:00 316 422 240 5:14 36:44:00 213 93 980 8:19 39:54:00 317 431 260 5:19 36:49:00 216 101 1000 8:24 39:59:00 317 440 280 5:24 36:54:00 219 109 1020 8:29 40:04:00 319 449 300 5:29 36:59:00 223 118 1040 8:34 40:09:00 318 458 320 5:34 37:04:00 227 128 1060 8:39 40:14:00 320 468 340 5:39 37:09:00 231 138 1080 8:44 40:19:00 321 477 360 5:44 37:14:00 234 147 1100 8:49 40:24:00 322 487 380 5:49 37:19:00 238 155 1120 8:54 40:29:00 322 496 400 5:54 37:24:00 242 164 1140 8:59 40:34:00 323 505 420 5:59 37:29:00 246 173 1160 9:04 40:39:00 324 515 440 6:04 37:34:00 251 183 1180 9:09 40:44:00 324 524 460 6:09 37:39:00 254 192 1200 9:14 40:49:00 325 533 480 6:14 37:44:00 258 201 1220 9:19 40:54:00 325 542 500 6:19 37:49:00 262 210 1240 9:24 40:59:00 325 552 520 6:24 37:54:00 266 219 1260 9:29 41:04:00 326 561 540 6:29 37:59:00 270 228 1280 9:34 41:09:00 326 569 560 6:34 38:04:00 273 237 1300 9:39 41:14:00 326 580 580 6:39 38:09:00 276 246 1320 9:44 41:19:00 327 590 600 6:44 38:14:00 280 254 1340 9:49 41:24:00 327 599 620 6:49 38:19:00 283 262 1360 9:54 41:29:00 327.1 607 640 6:54 38:24:00 286 272 1380 9:59 41:34:00 327.3 616 660 6:59 38:29:00 289 282 1400 10:04 41:39:00 327.5 626 680 7:04 38:34:00 292 291 1420 10:09 41:44:00 327.6 636 700 7:09 38:39:00 294 301 1440 10:14 41:49:00 327.7 636 720 7:14 38:44:00 297 310 1460 10:19 41:54:00 327.81 656 740 7:19 38:49:00 299 319 1470 10:24 41:59:00 327.7 659 760 7:24 38:54:00 301 329 1470 10:54 42:29:00 326.9 659 780 7:29 38:59:00 303 338 800 7:34 39:04:00 305 347 7:39 39:09:00 306 338 308 347 308 347 AGP TG4 8/22 4:30 PM Survey Run#2 Time of Hours Since Time of Hours Since Depth Reading Last Circ Temperature Pressure Depth Reading Last Circ Temperature Pressure 0 16:34 52 14 50 16:39 24:09:00 69 14 820 19:46 27:16:00 304 358 100 16:44 24:14:00 165 29 840 19:51 27:21:00 306 366 120 16:49 24:19:00 177 38 860 19:56 27:26:00 307 375 140 16:54 24:24:00 184 47 880 20:01 27:31:00 309 384 160 16:59 24:29:00 191 56 900 20:06 27:36:00 310 394 180 17:04 24:34:00 195 66 920 20:11 27:41:00 312 403 200 17:09 24:39:00 196 74 940 20:16 27:46:00 313 412 220 17:14 24:44:00 205 84 960 20:21 27:51:00 314 422 240 17:19 24:49:00 209 94 980 20:26 27:56:00 316 431 260 17:24 24:54:00 213 103 1000 20:31 28:01:00 315 440 280 17:29 24:59:00 216 111 1020 20:36 28:06:00 318 449 300 17:34 25:04:00 220 120 1040 20:41 28:11:00 317 458 320 17:39 25:09:00 223 130 1060 20:46 28:16:00 319 468 340 17:44 25:14:00 228 139 1080 20:51 28:21:00 320 477 360 17:49 25:19:00 231 147 1100 20:56 28:26:00 321 487 380 17:54 25:24:00 234 157 1120 21:01 28:31:00 321 496 400 17:59 25:29:00 239 166 1140 21:06 28:36:00 322 505 420 18:04 25:34:00 244 175 1160 21:11 28:41:00 323 515 440 18:09 25:39:00 247 183 1180 21:16 28:46:00 323 524 460 18:14 25:44:00 251 193 1200 21:21 28:51:00 324 533 480 18:21 25:51:00 255 202 1220 21:26 28:56:00 324 542 500 18:26 25:56:00 259 212 1240 21:31 29:01:00 325 552 520 18:31 26:01:00 263 221 1260 21:36 29:06:00 325 561 540 18:36 26:06:00 266 230 1280 21:41 29:11:00 326 569 560 18:41 26:11:00 270 239 1300 21:46 29:16:00 326 580 580 18:46 26:16:00 273 247 1320 21:51 29:21:00 326 590 600 18:51 26:21:00 278 255 1340 21:56 29:26:00 326.6 599 620 18:56 26:26:00 281 264 1360 22:01 29:31:00 326.7 607 640 19:01 26:31:00 284 273 1380 22:06 29:36:00 326.9 616 660 19:06 26:36:00 287 283 1400 22:11 29:41:00 327.2 626 680 19:11 26:41:00 289 291 1420 22:16 29:46:00 327.3 636 700 19:16 26:46:00 292 300 1440 22:21 29:51:00 327.4 646 720 19:21 26:51:00 294 311 1460 22:26 29:56:00 327.4 656 740 19:26 26:56:00 297 320 1470 22:25 29:55:00 327.81 659 760 19:31 27:01:00 299 331 1470 22:55 18:35:00 326.9 659 780 19:36 27:06:00 301 339 800 19:41 27:11:00 302 347 Guhl, Meredith D (DOA) From: Guhl, Meredith D (DOA) Sent: Monday, March 10, 2014 10:11 AM To: 'akutanadmin@gci.net' Cc: Davies, Stephen F (DOA); Schwartz, Guy L (DOA) Subject: Reporting Compliance South Elbow Well 4 Dear Mr. Scanlan: I am completing the final compliance check for South Elbow Well 4, PTD 210-073,API 50-295-20004-00-00, abandoned 9/15/2013. As previously requested by Steve Davies, on January 14, 2014, and required by Regulations 20.AAC 25.070 and 20 AAC 25.071,the following data is required: 2. Flow tests: pressure,temperature and flow charts and data (both qualitative and quantitative) recorded during every flow test. Please submit the raw pressure data from South Elbow Well 4. As required by Statute AS 31.05.030(d)(2)(B)and Regulation 20 AAC 25.050 (d)the operator shall file with the Commission (d)... a complete digital copy of each inclination... survey not previously filed must be filed with the commission in a format acceptable to the commission. An ASCII or Excel version of the final inclination survey is required for South Elbow Well 4. Please also supply a PDF of the final inclination survey. In addition,as required by Statute AS 31.05.030(d)(2)(B)and Regulation 20 AAC 25.070(2)and noted on the approved PTD letter dated July 22, 2010,the operator is required to file a final as-built survey plat showing the precise surface location of the well. Please submit an as-built for South Elbow Well 4. Finally, as required by Statute AS 31.05.030(d)(2)(B)and Regulation 20 AAC 25.071(b)(1)the operator is required to submit(1)a sepia and a reproduced copy of a complete mud log or a lithology log consisting of a detailed record and description of the sequence of strata encountered, including the kind and character of the rock...;an electronic image file in a format acceptable to the commission may be substituted for the sepia. Please submit a final paper mudlog, printed on accordion paper, and digital versions, in both PDF and LAS formats,of the mudlog as supplied by Prospect Geotech. Please provide the requested raw pressure data, digital versions of the inclination survey, an as-built survey plat,and paper, PDF and LAS versions of the mudlog by April 10, 2014. Please supply a phone number so I may contact you to assist with any questions you might have. Sincerely, Meredith Guhl Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission meredith.guhl@alaska.gov Direct: (907) 793-1235 1 FEB 19 2014 21 v - 67 3 239?g 23930 AKUTAN AOGCC 14"2M K BENDER UNIMAK ISLAND • AKUTAN ; UNALASKA ISLAND UMNAK ISLAND To: Guy Schwartz, Alaska Oil and Gas Conservation Commission From: Mary Tesche, Assistant City Administrator Date: February 19, 2014 Re: Akutan Geothermal Project Core Samples and Additional Information Mr. Schwartz: At the request of AOGCC, the City of Akutan is providing materials and information for the Akutan Hot Springs Well 2 and South Elbow Well 4, both part of the Akutan Geothermal Project. Below is an inventory list of the provided information: • Five(5) HSB-4 sample containers, labeled from 0' to 1500' • One (1) HSB-4 sample container, no label • Nine (9)HSB-2 sample containers, labeled from 0' to 830' • Binder - Supplementary Materials for Akutan Hot Spring Well 2 and South Elbow Well 4, with CD • Akutan Core Data DVD Please let me know if you need any additional information or have any questions. Cordially, 0•.i Mary Tesche Assistant City Administrator City of Akutan 907.777.1643 RECEIVED FEB 19 Z014 AOGCC Supplementary Materials for Akutan Hot Springs Well 2 and South Elbow Well 4 Contents Tab File Name File type 1 DrillingPaper_GRCVoI35 pdf 2 Summary of Findings—AGP TG Drilling FINAL2011 pdf Hot Springs Well - 2 folder South Elbow Well -4 folder Contents of folder Hot Springs Well - 2 Tab File Name File type 3 TG-2_Daily Drilling_Drilling_Reports pdf 4 AGP TG2 Flow Temperature Test 8.8.10 excel 5 TG-2_Temp_logsAll excel Contents of folder South Elbow Well - 4 Tab File Name File type 7 TG-4_Daily Drilling_Drilling_Reports pdf 6 AGP TG2 Flow Temperature Test with Air Assist 8.24.10 excel 8 TG-4_Temp_logsAll excel Akutan Geothermal Project Summary of Findings from the 2010 Exploratory Drilling Program Commissioned by City of Akutan, Alaska For the purpose of evaluating the geothermal resource in Akutan's Hot Springs Bay Valley 4 hi ill � ......_.r_ ..__—ire.: June, 2011 Investigators: Amanda Kolker, AK Geothermal Alan Bailey and W.T. Howard, Geothermal Resource Group Akutan Geothermal Project Summary of Findings from the 2010 Exploratory Drilling Program Introduction In summer 2010, two exploratory wells were drilled within a geothermal prospect area on the Island of Akutan, Alaska. Since the Akutan Geothermal area is roadless, the drilling operations were supported by helicopter. The planned program included the drilling of up to four small- diameter core holes, at locations given in Fig. 1. Due to budget constraints, only two of the four planned holes were actually drilled; these are marked with black arrows in Fig. 1. t .,f s F 31 32 33J "" I 11 I;0 a 1 1111 I 11-- '-'-`••••,..., '-'•-•"•••7"•, .4N,-•'," f /0,102 441111.1.111111W r , ., Jj ; } jar a ' 3 . sig . Ir----‘,. X111.. a.� :Di 11\ AA:.:,.:....--- ---�_� h —, ...A. "a „i4t . w le I II k ` a1 /l �� i it , / ' . ..-"4,-- ftoft < arsNssion lines'..,� � mAkuran _ r > - f' ." : : f • `1ei r /8T ,,•,,„,r - f . C' . r J. L . )' ',.' "' r � Miles 0.25 as 1 1.5 2 Fumaroles — Well Location qt Meter • 250 500 1,000 1.500 2,000 '`r;_-;:' ,•.,_7�� • Hot spring 04 . \\i ..�. c.r iy. I ••-Transmission Lines iapprox �'1 1..........77°,,,,. .. ' li �Akutan.r.�ect area ! Figure 1. Map of the Akutan Geothermal area, showing four original planned exploration well locations. The two holes drilled in 2010 are marked with black arrows. The core holes were intended to be temperature gradient ("TG") wells, providing TG data both at the time of drilling and in long-term monitoring efforts. Additionally, the drilling plan was designed so that any geothermal fluids encountered in the TG wells could be sampled and tested. Chemical compositions of well fluids were compared to hot spring and fumarole compositions to characterize the Akutan geothermal resource as a whole. Finally, detailed laboratory analysis of the core rocks was conducted as part of the TG drilling and resource assessment program. 2 Akutan Geothermal Project Summary of Findings from the 2010 Exploratory Drilling Program Planned drilling program Hot Springs well (TG-2) was to be drilled first. This well is sited directly above the outflow aquifer(s). The plan was to drill the Hot Springs well to TD of 1500 ft., OR to a depth where TG data was sufficient to constrain resource capacity. The goal for the Elbow well (TG-4) is to conceptualize the size of the outflow resource. This well was to be drilled second, also to TD of 1500 ft., OR to a depth where TG data was sufficient to constrain resource capacity. A diagram of the planned well design and wellhead assembly for both wells is shown in Figs 2-3. Throughout the drilling, downhole temperatures were recorded at 30' intervals with a maximum registered thermometer (MRT). These temperatures are not accurate records of the true geothermal temperatures due to the cooling effect of drilling fluids. However, the MRT readings do give a ball park idea of where hot zones are located. V A ■ r _ 5-W Oversize PQ Core to 150' HWT 11.2#/ft 4130 Butt Casing to 150'— . 3.78" 3.78"HQ Core to 600' 3'/z"HO 7.67#/ft 4130 Butt Casing to 600' 1.66"Tubing hung down from surface 2.98"NO Core to-1500' Figure 2. Well design for Hot Springs Well(TG-2), with a planned TD of 1500 ft. 3 Akutan Geothermal Project Summary of Findings from the 2010 Exploratory Drilling Program Casing Profile Casing Profile Well#2(Hot Springs) Well#1 (Near Fumarole) —0' —0' 8.5"ID hole; 8.5"ID hole; 7"casing(conductor pipe) 7"casing (conductor pipe) — _20' — I— _20' PQ hole; PQ hole; HW casing HW casing (4.5"O.D.) (4.5"O.D.) —150' —150' HQ hole HQ hole uncased HW casing (3.782"dia.) (3.782"dia.) —1500' —1500' Annular Blow Out Preventor Diagram \ NQ hole \ uncased accumulator (2.750"dia.) water 0•01 • storage •BO' toM BO'S -3500' Figure 3. Wellhead assembly design for Hot Springs Well (TG-2). Since temperatures upward of 250 °F were anticipated, a BOP was required for the wellhead. 4 Akutan Geothermal Project Summary of Findings from the 2010 Exploratory Drilling Program Summary of drilling activities Hot Springs Well (TG-2) In general, the drilling of TG-2 proceeded more slowly than anticipated. Drilling commenced on July 16, seven days after the planned start date. The holdup was due mostly to bad weather (low fog) prohibiting sling loading by helicopter, which delayed rigging up. Once drilling commenced, it was halted again at 37' due to the delayed arrival of a 9 7/8" bit. Figure 4. Photograph showing Hot Springs Well(TG-2)site and helicopter support. Photo by Neil McMahon,AEA. The hole was then drilled, cased and cemented to 157'. At 157', blow-out prevention equipment (BOPE) was installed and several tests were run, including a BOP test, formation integrity test, and other tests (accumulator, etc.). Beyond that, drilling proceeded in fits and starts as various problems arose and were mitigated (high torque necessitating bit changeouts, mud caking on sides of core barrel, stuck tubes, etc.). According to the drillers, many of these problems were due to the extreme heat and permeability of the formation at relatively shallow depths. Barite-weighted drilling mud (9.0 Ib) or CaCI Brine (9.6 Ib) was used throughout the drilling, and the hole required constant circulation because in most instances where circulation was stopped or slowed, the well flowed. The well showed a particular propensity to flow when the core rod was being pulled from the well due to changes in the annular pressure differential and the fact that it is not possible to run inside blowout protection (such as a float) inside of the core rod. While this makes drilling challenging, it is excellent from a resource perspective as it indicates high permeability. Between 585 and 587 ft., a fracture zone was encountered into which all drilling fluids were lost ("lost circulation.") The MRT reading at the fractured interval was 302 °F, then the well began flowing and another MRT was recorded at 359 °F. This was the maximum temperature recorded by MRT for the entire well. The fluid flow is shown in Fig. 5. 5 Akutan Geothermal Project Summary of Findings from the 2010 Exploratory Drilling Program kotrotiriseit Figure 5. Flow of 359"F fluids from fracture zone at 585'-587'.Photo by David Griggs,Major Drilling. At 603', another string of casing was cemented in and BOP and leak-off tests were performed. The leak-off test did not conform to state regulations, so a large amount of cement was squeezed around the shoe and into the surrounding formation. This cement job likely "sealed off"the productive fracture. From 603', equipment problems continued, with numerous bit replacements and tool-fishing jobs, until the hole was declared TD at 833'. After retrieving the core at TD, the hole was circulated for over two hours, and the pressure/temperature (P/T) logs were commenced. Table 1 shows zones of interest from TG-2, as identified from wellsite observations. Depth Mudlogger's notes 33' Artesian flow 122 degF 414' Drilling probs and well started flowing 588-590' Loss zone 613' Set casing shoe, LOT failed 733' Twisted off, hole started flowing 786' Ran survey, hole started flowing Depth Driller's notes Above 479' Full returns 479' Hot water coned up annulus, well flowed at^'120 GPM. Killed well. 590' Lost all returns Ran MRT. Well started flowing. Let well flow for 10 minutes to get sample, 593' then killed w/203 deg F at surface, 50 GPM flow. MRT=359F Cored 3-1/2" hole f/593 t/613'with no returns. BOP leak,failed squeeze test, 613' frac gradient 0.74 psi/ft. 793'-833' Cored 3.032" hole f/793't/833'. Lost 2-3 bbl/hr. Table 1. Table of zones of interest in TG-2, taken from driller's reports and mudlogs. 6 Akutan Geothermal Project Summary of Findings from the 2010 Exploratory Drilling Program Fig. 6 shows a diagram of the final wellbore configuration for TG-2. Fig. 8 shows graphical representations of drilling progress while on location for TG-2. — t2iow+d Lrrs �_ _� temsi FULL sal et3Tnnlb. 53 — 103 — 153 — ,. . 4 SOOria FULL sat at 15Tt on 20- Jul-10 207 - - 250 300 - 400 500 - - 1u = eii_I — y 3SM1e^.�FLOA set it8038ten2t _I — 700 — 750 — Pi 111.— 1 88hna HNO DN rat at 8188 on 084. -,0 Telel Depth 8998 Open mule Du meter 9 O92na Figure 6. Schematic of the final wellbore configuration for TG-2. Note 4%"casing to 157', 3%"casing to 603', and open hole until TD of 833'with diameter of 3.032". 7 Akutan Geothermal Project Summary of Findings from the 2010 Exploratory Drilling Program Geothermal Resource Group Well Name:Hot Springs Well Sect 32 Town:095 Rng:112W County.Aleutians East State:AK 0 • —al 103 —Actua cAsN Fanned '3 -- c 203 300 OTHEF -J _ I 400 TRIP - ." 5C0 ECOP-1\\ \of++. BOPO°S - _- 703 CEMENT - t. 8D3 tU D b03 EVALUATE - .. 1003 1103 - -' 1203 PROS,- - 1300 1403 -e:!. 1503 1 • 1 • I • I CE 10 '5 20 25 30 50 10.E 5 Days On Location Hours Figure 7. Graphical representations of drilling progress for TG-2. Graph on left shows days on location vs. drilling depth, note the difference between planned and actual. Chart on right shows the hours spent on various drilling- related activities. Elbow Well (TG-4) In contrast to TG-2, drilling proceeded more rapidly than anticipated at "Elbow well" or "TG-4." The drilling progress went very smoothly, with relatively few mechanical or equipment problems. There was very little lost circulation in TG-4, and all formation integrity tests (i.e., leak-off tests) were successful. While this was positive in terms of the pace of the drilling, it suggests that TG-4 has lower permeability than TG-2. TG-4 was "opened" with 9 '/$" bit to 38', and 33' of conductor was set from 5' to 38' (conductor has inner diameter of 6 5/81. Before the upper casing was installed at 186', a small amount of 8 Akutan Geothermal Project Summary of Findings from the 2010 Exploratory Drilling Program fluid was lost (5 bbls/hr) at 143,' and more between 168' and 188' (7-10 bbls/hr). This was in a zone of fractured tuff (relatively permeable layer) and a small temperature increase was registered at 150 - 156' and again at another fracture zone 185'. These are probably not substantial hot aquifers as temperatures only rose slightly after considerable halt in circulation, and regular circulation temperatures were still recording low (<212 °F). A cement plug was installed across the lost circulation zone (spanning 120-172'), and the hole was cased and cemented with HWT (4.5"). Equipment tests were run at 188', including BOP, annular preventer, diverter valve and other valve tests—all were successful. After several hours with no circulation, an MRT was run that read 180 °F (188'). The well was then drilled rather uneventfully - to 510', when the crew had to pull out for a C — Ground Letel - E.E25irs fUL_se:at 337 on 1_- new bit, and then had a stuck core barrel @ A4-11) 527'. At 596', the second string of casing 100 — was installed (HQ, with an inner diameter of - �`OO1rsfULLseta1186Ror,5- 200 — AJ9-1D 3.5"). Formation integrity tests and equipment tests were run at 600', including — - BOP, annular preventer, diverter valve and 300 _ other valve tests — all were successful. After — several hours with no circulation, an MRT 400 was run that read 265 °F (600'). 500 - From 600' to 1500', drilling proceeded very 95DoirbfUL_set a1556RDr,B rapidly with little to no communication 600 — ^"g1D between the drillsite and management due to lack of internet and cell phone coverage 700 — at the drillsite. Fig. 9 shows the final - wellbore configuration for TG-4, and Fig. 10 E00 - shows graphical representations of drilling 900 - progress while on location for TG-4. l 1000 — 1100 - Figure 8. Schematic of the final wellbore configuration 1200 ••1 for TG-4. Note 4 %" casing from 38' to 186, 3 casing to 596, and open hole until TD of 1500' with 1300 — diameter of 3.032". 1400 - I 1500 — � Tota DeDm 1.50C' Ober MDe Diameter 3 0321ns 9 Akutan Geothermal Project Summary of Findings from the 2010 Exploratory Drilling Program 0 , 100 1 —'IE—Actual —{7—Planned PROBLM 1. 0 200 t OTHER 2.50 300 ',# I 400 i '_ ,ii EVALUATE 500qv 600 cr +j. CASING ' : :: I ; + a 700 + I , Ii { TRIP " a 800 m I ' O 900 II : : ,� BOPOPS 1000 I 1100 \ MOB ii II _CEMENT 1300 1400 , -..c .._ 147.75 1500 • • 0 5 10 15 20 25 0 50 100 150 Days On Location Hours Figure 9. Graphical representations of drilling progress on TG-4. Graph on left shows days on location vs. drilling depth, note the difference between planned and actual. Chart on right shows the hours spent on various drilling- related activities. 10 Akutan Geothermal Project Summary of Findings from the 2010 Exploratory Drilling Program Temperature gradient data End-Of-Well Pressure/Temperature Surveys A Pressure/Temperature (PT) tool, or "memory" tool, was rented from Pacific Process Systems and used for the end-of-well PT surveys. Three runs were recorded. The first run was commenced 12 hours after circulation ended. The second run was recorded 12 hours after the first; and the third run was recorded 12 hours after the second. For every run, stops were made at 20 foot stations. Hot Springs Well 2 (TG-2) Results are shown in Figures 10-12, below. Because these surveys were taken so soon after the well was drilled, the temperature readings are still influenced by the cooling effects of fluid circulation.Therefore these are "unequilibrated" downhole temperatures. ACP T62 8.6.10 Run 1 Temp Suney -Pressure ---Temperature Tempereure Ext 500 -'"1, 300 450 400 250 750 700 2008 J250 � v 200 150 150 100 / 100 50 — 5C 0 3AM 6AM 6 Fn Ape 2010 Time Figure 10. First of three end-of-well P/T surveys at TG-2, with unequilibrated downhole temperatures shown in red; pressures shown in blue. Maximum T was 312 °F at 833'. The drop off in pressure shortly after hitting bottom is a result of the column lightening up as the well started to flow and the fluid started to flash to steam. The dramatic 11 Akutan Geothermal Project Summary of Findings from the 2010 Exploratory Drilling Program spike in the pressure and a corresponding decrease in temperature is from pumping CaCI solution down the hole to keep it from flowing. Note a drop in temperature at 4 am, corresponding to 603'which is where the casing shoe was set. AGP TG2 8.6.2010 Run 2 - Pressure -Temperature -Temperature Ext 350 300 300 250 250 nt a m 200 200 5 a n a $ 150 / 150 100 100 50 0 8PM 9PM 10PM 11PM 6 Fri Aug 2010 Time Figure 11. Second of three end-of-well P/T surveys at TG-2, with unequilibrated downhole temperatures shown in red; pressures shown in blue. Max T was 325 °F at 833'. Note a drop in temperature at-10 pm, corresponding to 603' which is where the casing shoe was set. 12 Akutan Geothermal Project Summary of Findings from the 2010 Exploratory Drilling Program AGP TG2 8.7.10 Run 2 Pressure -- Temperature Temperature Ext 350 300 300 250 250 a 3 5 200 200 m � N a a 150 150 100 100 50 0 50 8PM 9PM 10PM 11PM 30 Mon Aug 2010 Time Figure 12. Third of three end-of-well P/T surveys at TG-2, with unequilibrated downhole temperatures shown in red; pressures shown in blue. Max T was 331 °F at 833'. Note a drop in temperature at —10 pm, corresponding to 603' which is where the casing shoe was set. All three surveys show a drop in temperature occurring near the casing shoe at 603' and corresponding with the hot fracture zone between 585 and 587' that was cemented in. The apparent cooling is likely the result of cement injected across that entire area for the leak off test. An injection test was not performed on the Hot Springs Well due to time constraints and helicopter engine problems. 13 Akutan Geothermal Project Summary of Findings from the 2010 Exploratory Drilling Program Elbow Well (TG-4) End-of-well PT logs were run on TG-4 following the same method as for TG-2, with three runs recorded at 12, 24, and 36 hours after circulation ended (Figs. 14-16). Like at TG-2, these are "unequilibrated" downhole temperatures because these surveys were taken so soon after the well was drilled (and therefore the temperature readings are still influenced by the cooling effects of fluid circulation). AGP TG4 8/22/10 Run 1 Pressure Ternperalure -Temperature Eat 9 6so 1�t 1tc 01-11 ,14' I�i1v ipD 600 ^�8 \PI 300 N"' v ke 550 ti �a 4' Ok 7 P, abG� j��dl V 250 �� �� 2001 a a.300 0 `'1' lk 250 150 200 150 100 100 60 50 0 " 6AM 9PM 22 Sun Aug 2010 Time Figure 14. First of three end-of-well P/T surveys for TG-4, with unequilibrated downhole temperatures shown in red; pressures shown in blue. Maximum T was 327.1 °F at 1500'.Annotations highlight minor fracture zones that did not exhibit substantial permeability. 14 Akutan Geothermal Project Summary of Findings from the 2010 Exploratory Drilling Program AGP TG4 8.22.10 Run#2 Maximum Temperature a 327.52 Pressure -Temperature --- Temperature Ext 650 600 300 550 500 250 450 400 e 350 200 a a 300 $ 250 150 200 150 100 100 50 IF, OPM OPM 22 Sun Aug 2010 Time Figure 15. Second of three end-of-well PIT surveys,for TG-4 with unequilibrated downhole temperatures shown in red; pressures shown in blue.Max T was 327.5"F at 1500'. 15 Akutan Geothermal Project Summary of Findings from the 2010 Exploratory Drilling Program AGP TG4 8/23/10 Run I Final Survey MAXIMUM TIA4PFRA TURF-327.81 F - Pressure Temperature Temperature Ext 650 - ___ --_.; 600 300 550 500 250 450 400 3 350 200 l c .300 S 250 % 150 200 150 100 100 50 0 -50 6461 9AM 23 Mon Aug 2010 Time Figure 16. Third of three end-of-well PIT surveys, with unequilibrated downhole temperatures shown in red;pressures shown in blue.Max T was 327.8'F at 1500'. An injection test was performed on well TG-4 to determine its permeability (Fig. 17). This test suggests that the well has generally poor permeability. Akutan TG4 Injection Test 8/24, 2010 200 150 Pretstj(i _ +/- 165 PSI 100 Prepared by Prosper Geoteah 50 r80 PSI Stable crral5 0 PSI c_.._,t(Psi) Lr1 N O t\ Ln N O N Lf) N O N. Ui N O N Ln IN O N Ui IN O N CO T Lf) 0 r'I r-1 IN CO tt N O 1--1 ri IN CO Ch Ch N O r-1 Ci01 Q1 a1 a1 O O O O O O O O O O O O O r-1 .--I r-1 .--1 .-1 r-1 r-1 r-1 r-1 r-1 r-1 r-1 r-1 r-I r-I r-1 r-1r1 r-1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O O O O O r-1 .-1 r-1 r-1 r-I r-1 r•1 r-1 .-I 1-1 r-1 r-1 .-1 r-1 r-1 r-1 e-1 -I NN INI I 000000000000000000 ctINNINNINNNINCNINNNINNINNINN Cr \ \ \ \ \ \ \ \ \\ \ \\ \\ \ \\ \ \ \ vt Tr Tr cr \ - N N N N Cr Cr N N N IN N N IN N N IN N N 00 00 00 00 00 \ \ \ \ \ \ \ \ \ \ \ \\ \\ \ \\ CO CO CO 00 00 00 CO 00 00 CO CO 00 00 00 CO 00 CO CO Figure 17. Results from an injection test performed on well TG-4. 16 Akutan Geothermal Project Summary of Findings from the 2010 Exploratory Drilling Program Homer plots for TG-2 and TG-4 The end-of-well surveys were taken so soon after drilling was completed that the downhole temperatures were not likely to have equilibrated to the true formation temperatures. In order to predict the equilibrated downhole temperatures, we used the Horner method to extrapolate ultimate values for the reservoir temperature based on curves generated from the three end- of-well survey points from each depth. An example of an extrapolation is shown in Fig. 18, and the depth vs. temperature plot generated from extrapolated values is shown in Fig. 19. Closest fit 243.8 Meters 166.0 1662. 6 3 =-......_... .. _ 166-0 ._ ...... I 163.0 •S•1•1 164.0 161.0 .. _.... _.... ..... _..____ .. .. ....._.____.._..__.. 162.0 .. 106000/106 Figure 18. Graphic showing method for extrapolating the equilibrated reservoir temperature based on three temperature readings over time at a fixed depth interval at TG-2(here,243.8 m or 800 ft). 17 Akutan Geothermal Project Summary of Findings from the 2010 Exploratory Drilling Program Akutan TG Well Temperatures (F) 0 100 200 300 400 500 200 1-- 0 0 -200 - -400 J • a) -600 -800 "' -1000 —TG2 -1200 — -TG4 —Boiling Curve 0.1%NCG -1400 — —Flowing MRT TG2 I -1600 - Figure 19. Estimated equilibrated Temp v. depth plot for Akutan TG wells, based on Horner extrapolations of dowhole data (see Fig. 11 and text for details). Also shown is actual flowing temperature from 585'as well as a boiling point to depth curve assuming a fluid level at the surface. The TG-2 Horner plot shows a relatively rapidly increasing temperature gradient until ''80m (' 245') followed by a more slowly increasing gradient, and then a rapid drop in temperature between —150 and 175m elevation (460' and 540'). The Horner plot suggests equilibrated temperatures of 160 C in this zone between 150-170m, while a maximum reading thermometer provided 182 C in this zone during the flow test. Thus, this zone was still recovering from cementing during the drilling operations. The TG-4 Horner plot shows a relatively rapidly increasing temperature gradient until ' 900', transitioning to a slowly increasing temperature gradient from 900'-1500'. The minor temperature fluctuations from 900-1500' are probably a product of minor flow from small fracture sets. The fact that there was no temperature reversal and that the gradient continues to increase suggests there could be a deeper, hotter aquifer below 1500' that was not penetrated by drilling. 18 Akutan Geothermal Project Summary of Findings from the 2010 Exploratory Drilling Program Equilibrated Temperature Surveys: May 2011 While the end-of-well surveys were conducted with a memory tool, it was not possible to use a memory type tool for the post-completion logging due to the small inner diameter of the Akutan TG wells (ID > 1.5"). Due to this and other unique conditions of Akutan TG wells (high temperatures at shallow depths, remoteness of the wellsites, among others), temperature logging equipment was custom built for the job. A portable, hand operated wireline unit and counter was equipped with a thermistor and thermocouple cable to measure downhole temperatures. This tool logs temperatures only; it cannot record downhole pressures. On April 25-26 2011, Matthew Bereskin and assistants from the City of Akutan went into the field to prep and test the TG wells prior to running logs downhole. Equipment problems (wrong size packoff) prevented the logs from being run, and pressure readings were not taken due to a broken gauge. However, the crew was able to prep the wells and observe conditions at the wellhead. Both wells displayed "low pressure conditions." On 5/11/2011, the crew returned to the field to run a survey on TG-4. The crew was unable to get downhole temperatures in TG-2 was because the wellhead pressure had increased since the well was prepped two weeks prior. While no pressure measurements were taken at the wellhead, the crew reported that its valves were substantially more difficult to open, and after a delay of 20-30 seconds, fluid came out of the wellhead. According to the crew, the H2S meter did not detect any gas shows, but the crew could smell sulfur when the fluids reached the wellhead. Three hypotheses could explain why the wellhead pressure in TG-2 increased over a period of 18 days: 1. A mechanical failure of the check valve at the bottom of the tubing. If this is the case, the wellhead may have begun communicating with the reservoir pressure, whereas previously the wellhead was effectively isolated from the reservoir. 2. A gas cap has built in the well due to boiling of the static fluid in the wellbore. This boiling could have been initiated when the well was opened and prepped two weeks earlier. Boiling conditions would only exist in the upper 200 feet of the wellbore, and thus the wellhead pressure would be modest, corresponding to a couple of degrees C over boiling (Figure 20). 3. Lastly, reservoir pressures may have suddenly increased. Although no regional earthquakes or volcanic/magmatic activity were observed, the crew did note a change in the behavior of the other geothermal manifestations. Several of the hot springs near the well were reported to be boiling. The change in the behavior of the other geothermal manifestations could be explained by any of the scenarios above as well. The crew built a lubricator for TG-2, and was able to run a successful survey eleven days later, on 5/22/2011 (see photo of 5/22 survey, Fig. 20). At the time of writing,the City of Akutan crew was in the process of procuring a wellhead pressure gauge in order to obtain an accurate shut- in pressure for both TG wells. 19 Akutan Geothermal Project Summary of Findings from the 2010 Exploratory Drilling Program ;, ":"-1 r*1 � .004 Fig.20. City of Akutan crew collecting dowhole temperature logs,5/22/2011. Hot Springs Well (TG-2) On May 22, 2011, a temperature survey was run in TG-2 by a crew from the City of Akutan, led by Matthew Bereskin. The well was bleeding while the log was run, resulting in a minor steam or two-phase section in the upper 60-70 ft (20-25 m). Upon opening the valve, the well flowed a constant stream of hot water, which changed to steam after about 30-40 minutes. The steam "wasn't hot at all," indicating that it had probably been static in the wellbore for some period of time. At the time the log was run, the weather was "nice, overcast, with about 15 mph wind." No steam or water was seen leaking from around the wellhead. The survey took about 75 minutes, with a stop of 1 minute at each of the 20' intervals. There was a small amount of white mineralization on the inside of the wellhead. The crew reported a slight sulfur odor "but not too strong," and no H2S readings were recorded on personal monitors worn by the crew. Since the pressure gauge was not working, no stabilized shut-in wellhead pressure was recorded before they ran the log and during the run. However, the crew plans to go out within the next few weeks to collect a stabilized shut-in pressure reading. Results from the temperature survey are shown in Fig. 21. 20 Akutan Geothermal Project Summary of Findings from the 2010 Exploratory Drilling Program Akutan TG2 Temperatures Temp (F) 0 100 200 300 J a 400 a) • 500 ▪ea ' 600 W 700 — 12h 08-2010 24h 08-2010 800 36h 08-2010LT- May-11 J 900 i 0 50 100 150 200 250 300 350 400 Figure 21. Equilibrated temperature profile for TG-2,plotted with the three end-of-well heat-up surveys. The end-of- well surveys were taken 12 hours.24 hours,and 36 hours after circulation ended in August 2010;the equilibrated profile was obtained 9 months later in May 2011. The new temperature profile shows a distinctly different shape from the end-of-well temperature build-up profiles. Among the new features to note are apparent cooling in the upper 400', highest temperatures in the permeable zone near 585' MD (415' elevation), and a temperature reversal of about 5 C below the permeable zone to the bottom of the well. The top part of the well between appears to have cooled since the well was completed in August 2010. This probably reflects a trickle of water downflowing from around 200' MD and exiting into the formation at about 415' MD. It can only be a trickle of water because the water is heating up as it flows down behind the casing. Geologic descriptions in the mud log indicate a possible permeable formation near 200' and a permeable fracture at 415'.This cooling suggests the possibility of a poor cement job in the annulus between the permeable zones at 200' and 415.' While this does not present a significant safety concern (e.g. flashing in the wellbore or annulus causing casing collapse) it does highlight the importance of obtaining good cement jobs 21 Akutan Geothermal Project Summary of Findings from the 2010 Exploratory Drilling Program on the casing strings in order to both isolate cool fluids from the wellbore and to prevent subsurface blowouts. The new data also shows that the permeable zone at 585' MD (about 415' elevation) has fully recovered in temperature. This zone provides the highest temperature in the wellbore. Notably, the static temperatures measured in this permeable zone are about 170 C, which is lower than the 182 C temperature measured in this zone when the well was flowing. This raises the question of why the MRT provided a flowing temperature of 182 °C(359°F) at 178 m (585') when the static temperature of the well is about 170 °C (338 °F) in the most recent downhole temperature survey. While the MRT reading does appear to be correct based on silica geothermometry, this implies that the well was drawing in higher temperature fluids when it was producing. This suggests that TG-2 was drilled on the margins of a more permeable and hotter outflow path. The well was apparently drawing upon the higher temperature fluids during the flow test, suggesting the production zone is in proximity to the higher temperature zone but that it has a relatively low permeability connection to this zone. The slight temperature reversal of about 5 C below the permeable zone is consistent with the geologic model that the thermal features in Hot Springs Bay Valley represent a confined lateral outflow from a geothermal reservoir located further west. Elbow Well (TG-4) On May 10, 2011, a temperature survey was run in TG-4 by Matthew Bereskin and assistants from the City of Akutan (Figure 23). The temperatures encountered in the May survey differed very slightly from the end-of-well temps, which is not surprising in light of the fact that that well was relatively impermeable and exhibits a temperature profile that shows heating primarily from conduction. 22 Akutan Geothermal Project Summary of Findings from the 2010 Exploratory Drilling Program Akutan TG4 Temperatures Temp(F) 0 - 200 • 400 - N 600 p \ a 000 cu 1000 0 ea aL, 1200 W 1400 -12h 08-2010 -24h 08-2010 1600 36h 08-2010 -05-2011 1800 0 50 100 150 200 250 300 350 Figure 23. Equilibrated temperature profile for TG-4,plotted with the three end-of-well heat-up surveys. 23 Akutan Geothermal Project Summary of Findings from the 2010 Exploratory Drilling Program TG data analysis A comparison of the static temperature profiles in TG-2 and TG-4 shows that the temperatures in the upper 200 m of TG-4 are lower than in TG-2 (Figure 24). The upper portion of TG-4 is being conductively heated by the geothermal system. However, the lower temperatures indicate that TG-4 is further from the shallow outflow path. No conclusions can be drawn from the temperature profiles as to whether additional high temperature permeable zones underlie either TG-2 or TG-4. Akutan TG Well Temperatures May 2011 (F) -200 0 200 �- 400 600 15 800 cu4- 0 0 1000 - z f „—°J, 1200 - TG2-05-2011 1400 TG4-05-2011 1600 -Boiling 0.1%NCG 1800 — — -- 150 200 250 300 350 400 450 Figure 24. Equilibrated well profiles for both Akutan TG wells,shown with a boiling point with depth curve for water with 0.1%non-condensible gas content. An output capacity for the maximum temperature fluids produced by TG-2 was estimated in 2010 based on the flowing temperature of the well and assumptions about flow rate. However, 24 Akutan Geothermal Project Summary of Findings from the 2010 Exploratory Drilling Program more recent data indicate that such estimates may have been overly optimistic, as they used assumptions for wellhead flow capacity that now appear to be inaccurate. Studies of alteration minerals in the core suggest that the "aquifer" discovered by TG-2 is likely to have significant permeability limitations (Stelling and Kent, 2011). Additionally, more recent temperature logs indicate that the well was drawing in higher temperature fluids when it was producing. The prediction of productivity of production well drilled and completed to a similar depth as TG-2 was based on the preliminary results from drilling. Productivity calculations were made with the following assumptions based on observations at the wellhead: • The well is making two-phase flow. • 50 gpm was measured at the surface. • A column of water from surface to the production zone at 585 -587 feet. • Only water was being produced from the fracture at 585 -587 feet where the fluid enters the 4.50 inch hole. The standard enthalpy formula was used to obtain the total mass flow at the surface. Prittchett's formula, an empirical calculation based on several geothermal field observations, predicts the deliverability of a full sized production well completed to a similar depth as TG-2 (See Appendix B for calculations). The outcome of these calculations was an extrapolated volume (in gallons per minute, or "GPM") for a production well. That number can be used to convert the GPM of the full sized well into MW using Ormat conversion tables at 360° F (see Appendix B for conversion tables). These conversion factors are for ORC units manufactured by Ormat, Inc. There are other manufacturers of ORC turbo generators but all conversion factors are similar. In all probability a production well similar to TG-2 would be a well completed with 13 3/8", 54.5 ppf, K-55 buttress casing so that a 12" downhole pump could be run in the casing and the well would be pumped. Water (brine) would be pumped to the surface and run through a Rankine cycle ("ORC")turbo-generator. Pritchett's forumula calculations yielded an extrapolated pumped capacity of the TG-2 resource ranging from 465 to 820 gallons per minute. Based on the Ormat conversion tables and above assumptions, it is estimated that a production well with the same flow characteristics as TG-2 would produce 1.34 MW if completed near to TG-2 up to a maximum of 2.38 MW. Again, this estimate contains a high degree of uncertainty, because the flow assumptions for this estimate appear to have been overly optimistic. 25 Akutan Geothermal Project Summary of Findings from the 2010 Exploratory Drilling Program Geology The following descriptions are based on wellsite observations only. Wellsite geology was recorded by Jim Hill of Prospect Geotech, Inc., and full core logs are provided in Appendix A. Detailed laboratory analyses on the core rocks occurred in 2011 with the results published under a separate report (Stelling and Kent, 2011). Hot Springs Well (TG-2) Core logs for TG-2 commenced at 5' from the bottom of the cellar. Complete well logs are provided in Appendix A. In general, the formations encountered by well TG-2 are generally homogeneous volcanic flows of andesite, basaltic andesite, and basalt. While heavy oxidation (Fe oxides) was observed between flow layers, hydrothermal mineralization was confined to small (<1') fractures within the flows. Fig. 25 gives an example of a typical core box for well TG- 2. 0513 ez, '2q.5 / cgii h, t - — 2 F 3 a y .t - . 11 1 f * 1 a r Y r �� I v• a" lamisim mom Figure 25. Example of a typical 10'core box from well TG-2 containing andesite(sections#1-11 in photo)and andesitic tuff(sections#11-15 in photo). 26 Akutan Geothermal Project Summary of Findings from the 2010 Exploratory Drilling Program Summary descriptions of the geology of TG-2 are as follows: An unconsolidated till/clay layer was encountered from 4' to 23.' That layer was comprised of gray-brown pebbly silt and clay (quartz and mafics), containing abundant andesite and scoria clasts. A lahar/breccia layer was encountered between 23' and 52,' with angular andesite and basalt clasts in a clayey matrix. The top of bedrock was encountered at 52', with fractured andesite flows interbedded with thin (<1') tuff layers. The andesite was dark gray, mesocratic, porphyritic, and often vesicular, especially near the top or bottom of a flow. Phenocrysts were altered plagioclase and pyroxenes. Rare quartz as well as olivine were observed. Between 52' and 290', the bedrock was andesite, andesitic basalt, and basalt, with one small tuff layer at 220-221'. Andesitic basalt was dark grey, melanocratic, aphanitic, and locally chloritized. It contained microcrystals of altered plagioclase and mafics, and mineralized vugs near the tops and bottoms of flows. The basalt was described as dark greenish blue gray, aphanitic to microporphyritic, with small plagioclase and pyroxene phenocrysts, and rare olivine.. Fig. 26 shows an example of a vesicular flow margin. • X a a. * • Figure 26. Example of a vessicular top of a basaltic andesite lava flow in well TG-2. From —292' to 390', a new layer was encountered that is henceforth described as "lithic basalt." This basalt flow is moderate gray to greenish gray overall, and contains multicolored clasts of grayish red purple, red, pink, and black/brown lithic fragments (mostly basalt/andesite). Clasts range from angular to subangular to rounded, porphyritic to aphanitic, and range in size from <1 to >20 cm (ave. size 10 mm). The lithic basalt formation is very well-indurated and does not contain abundant fractures in comparison to the non-lithic flows. From 390' to TD (833'), the formation consists of interlayered lithic basalt, andesite and basaltic andesite, and small tuff layers. The 585'-587' productive interval was a highly vesicular and fractured layer within a dark gray, aphanitic basalt (Figure 27). The productive fracture was part of a larger set spanning 583' —590'. 27 Akutan Geothermal Project Summary of Findings from the 2010 Exploratory Drilling Program In the basalt and andesite flows, fractures were oriented in 2 distinct directions: 1) generally subhorizontal (25 degrees off vertical) and 2) subvertical. The subhorizontal fractures were larger and more open, and often mineralized with sulfides (mostly pyrite and arsenopyrite) and a fine-grained white mineral. The subvertical fractures were very small (1-2 mm) and almost always mineralized with calcite or laumontite. Laumontite and calcite also comprised most of the vein and vug fill in TG-2. AS 34. 19 .61g < .521 . l �, . 111 ..ei IMIL - - 11;_* 4 \dia..:„ irlia ._ : . :. . , ...: _. Figure 27. Core box showing the productive interval from TG-2(dark sections). Hot water at 359°F issued from a fractured and highly vesicular top of a basalt flow(sections#11-15 in photo). Note the darker color of the productive interval is because the rock remained wet for hours after core was pulled.Also note the mineralized subvertical vein in the rock just above the productive interval. Secondary minerals in TG-2 included abundant calcite, laumontite, chlorite, unidentified clays and zeolites, selenite, laumontite, and sulfides (pyrite and arsenopyrite, rare cinnabar). Rare silica deposits were observed. Hairline suvbertical fractures were filled with laumontite or calcite. Above —581', the vugs in vesicular portions of the flows were filled with a combination of calcite and chlorite. Between "'581' and 710', the vugs in vesicular portions of the flows were filled with a combination of calcite, chlorite, epidote, and rare laumontite. The productive fracture at 585'-587' had calcite, laumontite, chlorite, epidote, arsenopyrite, and cinnabar. Within the productive fracture and some vesicles below 581', epidote displayed an interesting morphology, with radiating euhedral crystals nucleating on top of chlorite vein fill. Cinnabar was observed in trace amounts below 581'. Additional mineralized zones occurred at 690' and 28 Akutan Geothermal Project Summary of Findings from the 2010 Exploratory Drilling Program 705', though the fractures in these zones did not appear to support large-volume fluid flow. Epidote was not observed below "710, though pyrite and other sulfides, and chlorite, continued below this zone. Elbow Well (TG-4) Core logs for TG-4 commenced at 5' from the bottom of the cellar. Complete well logs are provided in Appendix A. In general, formation encountered was largely the lithic basalt flow, as described in the TG-2 geology description. Summary descriptions of the geology of TG-4 are as follows: Between 5' and 57', the formation encountered was a sandy and pebbly unconsolidated glacial till deposit. The till was described as olive gray silicic groundmass with oxidized andesite clasts. Bedrock was encountered at 57' — a heavily oxidized top of an andesite flow. From 57' to 316' the formation consisted of interbedded andesite, basaltic andesite, and basalt flows, with the bulk of the formation being lithic basalt. These flows were olivine- and pyroxene-bearing, with abundant plagioclase phenocrysts, and exhibited a high degree of chloritization throughout. From 316' to 425' a thick bed of "lithic tuff' was encountered. This tuff was a dark grey, aphanitic groundmass with plagioclase and magnetite phenocrysts and small scoria clasts. The tuff showed chlorite alteration in vesicles and contained sulfide (possibly arsenopyrite) aggregates in fractures, but no calcite. Interbedded basalt, basaltic andesite, and andesite flows resumed from 425' to TD of 1500'. Several textural/compositional changes were noted within flows, typically accompanied by a minor amount of hydrothermal mineralization. Slickensides were noted in small, near-vertical fractures in andesite at 447', along with minor Fe0 staining. Fractured zones were observed from 468'-470' with a minor amount of fluid flow (fractures were "wet") and flowline temperatures increased slightly after that. Other notable fracture zones were observed at 542- 545' (with calcite, laumontite and chlorite), 627.5'-628.5' (brecciated with calcite and arsenopyrite), 764' (with laumontite, calcite, and clays), 787' (with calcite, cinnabar, arsenopyrite, and quartz), 977'-979' (with chlorite and quartz). From 979' to TD at 1500', only very minor fracture zones were observed. Secondary alteration minerals included chlorite, epidote, sulfides (pyrite, arsenopyrite, and rare cinnabar), laumontite and other unidentified zeolites, calcite, and quartz below 787'. It is interesting to note that compared with TG-2, well TG-4 contained very little secondary laumontite; most of the carbonates observed were calcite. Alteration minerals occurred interstitially, in fractures, in vesicles, and in contact zones and the tops of new flows. Fig. 28 shows an example of a relatively shallow fracture zone that has been sealed by hydrothermal mineralization. 29 Akutan Geothermal Project Summary of Findings from the 2010 Exploratory Drilling Program Mt i -,ir,et Jr ems., 111 .-lor -es, . y, -.p,._ ....it<.gyp. f L ,.gps. - 40 Fig 28. Fractured zone from 185'-186' in well TG-4. Fractures are filled with amorphous calcite, epidote, and sulfides(pyrite, arsenopyrite, and possibly cinnabar). Geologically, the formations encountered in well TG-4 were fairly impermeable. The basalt, and andesite flows contained relatively few fractures, almost all of which were "sealed" with mineral deposits. The tuffs and lithic tuffs were not particularly permeable either. However, there are abundant high-temperature hydrothermal alteration minerals present in the rocks, even at very shallow depths. For example, the hydrothermal mineral epidote, which is an index mineral indicating hydrothermal temperatures upward of 350 °C, was observed at very shallow depths—this is surprising and does not correspond to observed downhole temperatures. Slickensides observed in well rocks could be related to a possible range front fault on the SW side of the valley near well 4. This fault was identified from observations of terrace faulting up the hill to the SW, and lineations downvalley to the SW through the alluvial fans, noted by wellsite geologist Jim Hill. According to Mr. Hill, the faulting looks fairly recent since vegetation has not grown back over the disturbed area. A number of brecciated zones were observed in TG-4 (Fig. 29), but most were "sealed" with secondary mineral deposits and therefore probably do not represent active faults. Apr ••=44,t 1.,`"-str, „+r ^, Figure 29.Brecciated fracture zone with secondary calcite deposit from a depth of 213'in TG-4. 30 Akutan Geothermal Project Summary of Findings from the 2010 Exploratory Drilling Program Fluid chemistry and geothermometry Well Fluids Two fluid samples were collected from TG-2. A sample was collected while the productive interval (585' —587') was flowing. The fluid temperature for that sample was 359 °F (182 °C). A second sample was collected from the bottom of the well. The fluid temperature for that sample was 212 °F (100 °C) at the surface. Since fluid samples were taken at the flowline at sea level pressures, the temperature cannot exceed 212 °F (100°C). Only one sample was collected from TG-4; a sample from the bottom of the well. The well did not flow so the sample had to be air-lifted out of the hole. The fluid temperature of the sample was 212 °F with air assist at the surface. The fluid samples were taken at the flowline at sea level pressures, therefore the temperature cannot exceed 212 °F. Geothermometry calculations from Akutan well fluids are provided in Table 2. A detailed chemical analysis of Akutan geothermal fluids is given in Rohrs, 2011. Sample Wellhead T(°C) Si(Qtz) Na-K-Ca Na/K TG-2 frac 182 184(Adiabatic) 212 217-232 TG-2 BH 100 227(Conductive) 197 246 TG-4 BH 100 95(Conductive) 210 328 Table 2. Geothermometry calculations for Akutan well fluids waters. Geothermometers computed using Powell and Cumming(2010), based on Giggenbach(1991)and Fournier(1989). Fumaroles On Thursday 8/26/10, Pete Stelling and Rich Gunderson were helicoptered to the Akutan fumaroles site to sample the fumaroles. The following is taken from Mr. Gunderson's notes: "Upon arrival we reconnoitered the approximately 100m x 80m area for steam vents appropriate to sample... Since we carried only a funnel for fumaroles sampling, we looked for relatively weak or "frying pan" type vents. The area had four high-volume/velocity steam vents more-or-less aligned at even elevation across the hillside (one large and very vigorous mudpot and three high velocity steam vents) but we weren't prepared/able to sample any of these. We did sample three moderately active "frying pan" vents with the funnel set-up, and apparently got good quality samples. At each of these vents we collected duplicate non-condensible gas (NCG) samples and single samples of steam condensate, steam condensate for isotopic analysis, and acid sulfate water(filtered, unacidified)for checking CI and F contents. Based on the timing and appearance of the NCG samples (about 20 minutes/sample, bottles 1/3 full of liquid, deep yellow-orange color), the steam appears to have low-moderate NCG and moderate H2S content. Our H2S monitors only sounded one time, and that was when we were about 1m in front of a 31 Akutan Geothermal Project Summary of Findings from the 2010 Exploratory Drilling Program vigorous steam vent trying(unsuccessfully)to capture its flow with the funnel. Temperatures of the sampled vents were 100°C, 99°C, and 99°C for samples AGP-8-26-10-10, -20, and -30, respectively at about 5" below the ground surface... "My overall impression of the thermal area was quite positive from a geothermal exploration point of view. The overall heat flow was impressive with the four large vents and the hundreds of smaller ones dispersed around the area. The alteration was intensive throughout and around the thermal area (white alteration was also noted but not visited in a drainage several hundred meters SE of the fumaroles). The alteration primarily consisted of (smectite?) clay (mostly medium gray, but locally beige,white, and other colors), but little time was spent characterizing it. No obvious sulfides were observed, and native sulfur was only observed in a few places. There was a normal (or moderate) smell of H25 throughout the area. The NCG samples all appeared to yield similar, moderate gas/steam ratios, and based on the rate at which the sample s changed color during sampling, did not appear to be excessively rich in H2S, Overall this thermal area appeared to be a typical geothermal-related (not magmatic) fumaroles area from a strictly sensory evaluation... "The geochemical samples we took were intended to A) characterize the steam as either geothermal or magmatic in origin; and B) if geothermal, estimate an equilibrium temperature at which the gases equilibrated (presumably the reservoir temperature underlying the fumaroles). The former (magmatic v. geothermal) can be evaluated by the Cl and F levels in steam condensate and in the acid sulfate waters as well as by the gas ratios within the NCG samples. The latter (equilibrium temperature) can be evaluated through various combinations of dry gas ratios using gas geothermometry grids..." Chemical analyses of non-condensible gasses and condensate from the fumaroles were conducted in 2010-2011.The analytical results,gas geothermometry, and other interpretations was is given in a separate report (Rohrs, 2011). 32 Akutan Geothermal Project Summary of Findings from the 2010 Exploratory Drilling Program Conclusions The 2010 exploratory drilling program identified an outflowing geothermal resource of 359 °F at depths of less than 600 ft. While this is an encouraging temperature for development, recent temperature profiles from the productive well did not reproduce these temperatures, suggesting that location would be a risky production target. Additional risks associated with developing this shallow resource are described in detail in separate reports (Kolker et al, in preparation; Rohrs, 2011; Stelling and Kent, 2011). Since volume could not be measured in the Akutan core holes, calculations based on empirical geothermal field observations were used to predict the deliverability of a full sized production well completed to a similar depth as TG-2. However, recent data suggests that this could be overly optimistic due to permeability concerns in the drilled formation. Geochemical data indicate that higher-temperature fluids exist at accessible depths in Hot Springs Bay Valley. However, whether these fluids are accessible by drilling has not been confirmed by the current drilling effort. A Resource Assessment study (in preparation by the author) is exploring this possibility through conceptual modeling of the geothermal resource. However, true confirmation that an accessible high-temperature / high-permeability resource exists is only possible with the drilling of larger-diameter wells. List of Appendices • Well logs for TG-2 and TG-4 • Excel spreadsheet containing well productivity calculations and power conversion tables References Stelling and Kent, 2011. "Geological Analysis of Drill Core from Geothermal Gradient Wells HSB2 and HSB4." Unpublished report to the City of Akutan. Rohrs, 2011. "Geochemistry of the Akutan Prospect." Unpublished report to the City of Akutan. Kolker et al, in preparation. AKutan Geothermal Resource Assessment. Unpublished report to the City of Akutan and the Alaska Energy Authority. Acknowledgements Many thanks to Jim Hill, Matt Bereskin and assistants, Pete Stelling, Bill Cumming, and David Rohrs for their contributions and input to this report. 33 GRC Transactions,Vol. 35, 2011 The 2010 Akutan Exploratory Drilling Program: Preliminary Findings Amanda Kolker', Alan Bailey2, and Wendell Howard2 'AK Geothermal 2Geothermal Resource Group, Inc. Keywords hot springs,it has been the subject of geothermal resource studies Akutan, Hot Springs Bay Valley,Alaska,Alaska Geothermal, since 1979.In summer 2010,an exploration drilling program was Aleutians,Aleutian Islands Geothermal, exploration drilling, carried out with two TG wells drilled in Hot Springs Bay Valley. AGP,City of Akutan,drilling exploration,resource assessment Since the Akutan Geothermal area is roadless,the 2010 drilling operations were supported by helicopter. The 2010 program included the drilling of up to four small-diameter core holes, at ABSTRACT locations given in Figire 1. Due to budget constraints, only two of the four planned holes were actuallydrilled;these are marked In 2010, a geothermal exploratory drilling program was with black arrows in Figure 1. conducted on Akutan Island,Alaska.The purpose of the drilling program was to obtain temperature gradient data to constrain Planned Drilling Program resource capacity.The wells were designed to allow long-term monitoring and possible testing of the Akutan geothermal field. The 2010 exploratory drilling plan was designed for long-term The 2010 drilling operations were carried out using wireline monitoring and possible testing of the Akutan geothermal field. core equipment and were supported by helicopter. Two wells The hole(s) were completed as temperature gradient wells and were drilled to respective depths of 253.9 meters and 457.2 available for future monitoring and testing.Additionally,detailed meters. The first well (TG-2) was drilled directly above an analysis of the core will be conducted at participating universities. outflow aquifer(s). A preliminary analysis of the TG-2 well These studies will be combined into a resource model that will be showed that the well made 2-phase flow with a 190 liter per minute liquid phase via a 96 mm hole and from a depth of 177 _> �'"!'_'� / to 178 m. The second well (TG-4)was drilled at the margins �;" �� �•� �' of the modeled outflow in order to conceptualize the size of I ; J 1� . _, t �'"�� the outflow resource. That well had very low permeability but _ .. displayed a high temperature gradient, with an extrapolated JI► • , _ 1 .s: it, temperature of 164 deg C at 457 m.Some evidence that a deeper, 45.-, J. :` ,� hotter resource exists at or near the TG-4 site was found using „5:, \ ,tom mineralogical data. Preliminary analysis of data suggests that '%'' ' . " i. a pumped production well at the TG-2 site would be capable of =� ! , ,� �k a maximum production of 2.3 MW Geochemical sampling of I _• "'•a ',ate_' the fumarole gasses was carried out on the flank of the Akutan �► �` >C -z`�- i 1 Volcano concurrent with the drilling. The data obtained from "' . 37 xi .,r drilling will be combined with core and geochemical analysis v, .,e- - .„ } ger . in order to form a resource model of the field preliminary to ,,- , , - - production drilling. - r` .� - �, Introduction ."`� Figure 1.Map of the Akutan Geothermal area,showing four original Akutan Island is located 790 miles southwest ofAnchorage and planned exploration well locations.The two holes drilled in 2010 are 30 miles east of Dutch Harbor.As a volcanic island with accessible marked with black arrows. 847 Kolker,et al. ised to determine the locations and depths of production holes, cm)kerf on the bit. The hole was cased using HWT casing and and in planning geothermal development. cemented. Blow-out prevention equipment(BOP)was installed Well TG-22 was drilled first. This well was sited directly and BOP and formation integrity tests were performed. Drilling above the modeled outflow aquifer(s). Well TG-4 was sited at resumed using HQ tools(9.6 cm). Drilling proceeded slowly as the margins of the modeled outflow in order to conceptualize the various problems (high torque, sticking and lost returns) arose size of the outflow resource.A diagram of the planned well design and were mitigated. The problems were due primarily to the ex- for both wells is shown in Fig 2. treme heat and permeability of the formation at relatively shallow depths. Barite-weighted drilling mud(1.08 kg/L)or CaC1 brine (1.15 kg/L)was used throughout the drilling,and the hole required • constant circulation because in most instances where circula- tion was stopped or slowed,the well flowed.The well showed a particular propensity to flow hen e core rod was being led 413 97 HWT 11size2e t 4 C30 reB to 45 7m from the well due to changes Vin the hannular pressure diffe ential —11 43 cm 11.2tlM 4130 Butt Casing to- 45 7m and the fact that it is not possible to run inside blowout protection when wireline coring. 9 6 cm HO Core to 162 9m Throughout the drilling,downhole temperatures were recorded —6.89 cm HO 7.67#! 4130 Butt Casing to- 1822 9m at 30'intervals with a maximum registering thermometer(MRT). These temperatures are not accurate records of the true geothermal —4.22 cm Tubing hung down from surface— temperatures due to the cooling effect of drilling fluids.However, the MRT readings do give a ball park idea of where hot zones are located. Between 178.31m-178.92m a fracture zone was encountered into which all drilling fluid returns were lost. The MRT reading at the fractured interval was 150°C. Soon afterward the well began 7 57 U„No core a-4572 m flowing and another MRT was recorded at 181.7 °C. This was Figure 2.Well design for Hot Springs Well(TG2),with a planned TD of the maximum temperature recorded by MRT for the entire well. 457.2 m. At 183.79m, an intermediate string of 8.89cm casing was cemented in, and BOP and leak-off tests were performed. The Summary of Preliminary Drilling Results leak-off test did not conform to state regulations, so a large amount of cement was squeezed around the shoe and into the Drilling Operations surrounding formation. This cement job likely "sealed off' the In general,the drilling of TG-2 proceeded more slowly than productive fracture. anticipated.The delays were caused by a combination of the bad From 183.79m, drilling was resumed using NQ (7.57 cm) weather conditions and supply line problems notorious in Alaska's tools. Drilling was halted at 253.9m due to ongoing difficulties Aleutian Islands;and equipment problems associated with drilling related to high temperature and tool failure.After retrieving the an extremely permeable and hot well with a core rig. core at TD,the hole was circulated for over two hours, and the A 16.97 cm conductor was installed at 8.53 m.The hole was pressure/temperature(P/T)logs were commenced. then drilled to 47.85 m using PQ tools with an oversized(13.97 In contrast to TG-2, drilling proceeded more rapidly than anticipated at TG-4,with relatively few mechanical or equipment problems. There was very little lost circulation in TG4, and all formation integrity tests(i.e.,leak-off tests)were successful.While this was positive in terms of the pace of the drilling, it suggests that TG4 has lower permeability than TG2. 10.06m of 16.9cm conductor was set from 11.58m, and the hole was drilled out with a 13.97cm kerf PQ bit. Before the surface casing was installed at 186',a small amount of fluid was lost(5 bbls/hr)at 43.59m and more between 51.2m and 57.3m (7-10 bbls/hr). This was in a zone of fractured tuff(relatively -- �� permeable layer)and a small temperature increase was registered at 45.72m—47.55m and again at another fracture zone 56.39m. These are probably not substantial hot aquifers as temperatures only rose slightly after considerable halt in circulation,and regular circulation temperatures were still recording low (<100 °C).A cement plug was installed across the lost circulation zone(span- ning 36.58m-52.43m),and the hole was cased and cemented with HWT(11.43cm OD). Figure 3.Photograph showing Hot Springs Well site and helicopter sup- The hole was drilled to 181.66m using HQ(9.6cm diameter) port.Photo by Neil McMahon,AEA. tools, and a second string of casing was installed (HQ, with an 848 Kolker, et al. outer diameter of 8.89cm).After testing the BOP and drilling out Akutan TGH Temperatures to 182.88m with NQ(7.57cm diameter), a leak-off test was run. Temp(C) Leakoff did not occur before reaching a 1.2 psi/ft gradient,so test- 0 50 100 150 200 250 ing halted and drilling was resumed. The well was TD'd at 457.2m. 50 0 PT Data -so A memory-type Pressure/Temperature(PT)tool was used for aoo — J the end-of-well PT surveys. Three runs were recorded at 12,24 a -iso and 36 hours after circulation ended. For every run, stops were made at 6.1m stations. Because these surveys were taken so E 200 soon after the well was drilled,the temperature readings are still -zso influenced by the cooling effects of fluid circulation. Therefore W the data represent unequilibrated downhole temperatures. -300 — In order to predict the equilibrated downhole temperature, -350 —-TG4 �eanreCune 0.1%NCc we used the Horner method to extrapolate ultimate values for the 400 _F0,irg MR- reservoir temperature based on curves generated from the three survey points from each depth. An example of an extrapolation 450 is shown in Figure 4. Figure 5.Plot of Homer-extrapolated TG data from Akutan Geothermal The final depth vs.temperature plot generated from extrapo- Wells TG-2 and TG-4.Also shown is the single MRT reading at productive lated values is shown in Figure 5. interval 178.31-178.92m prior to cementing.Maximum temperature was 181.67°C at 178.31m. closestfd 243.8 Meters ..• Geology ..._ '166g� Complete mud logs were recorded for both TG wells.In gen- eral, the formations encountered were generally homogeneous �* volcanic flows of andesite, basaltic andesite, and basalt. While heavy oxidation(Fe oxides)was observed between flow layers, I'"" hydrothermal mineralization was confined to small (<30cm) fractures within the flows.Figure 6 gives an example of a typical core box for well TG2. ,.,< In the basalt and andesite flows,fractures were oriented in 2 distinct directions: 1)generally subhorizontal(25 degrees off ver- 11.000/90001 tical)and 2)subvertical.The subhorizontal fractures were larger Morwer and more open,and often mineralized with sulfides(mostly pyrite Figure 4.Graphic showing method for extrapolating the equilibrated reser- and arsenopyrite), zeolites such as laumontite, and adularia and voir temperature based on three temperature readings over time at a fixed depth interval at TG2(here,243.8 m or 800 ft). M 424S Y3V Although the downhole surveys show a drop in temperature between 179.83m and 188.98m, we know that the downhole temperature was actually 181.67 °C between 178.31-178.92m from the MRT reading.The apparent cooling is likely the result of cement injected across that entire area for the leak off test. 411111Pli The plot of the extrapolated temperature vs depth for Well TG4 shows a relatively rapidly increasing temperature gradient • until–274.32m,transitioning to a slowly increasing temperature gradient from 274.32m-457.2m.The minor temperature fluctua- tions from 274.3m-457.2m are probably a product of minor flow from small fracture sets.The facts that there was no temperature reversal and that the gradient continues to increase suggest there - - - -- could be a deeper, hotter aquifer below 457.2m that was not s - IMO penetrated by drilling. An injection test was performed on well TG4 to determine its permeability.This test suggests that the well has generally poor Figure 6.Example of a typical 3.05m core box from well TG2 containing permeability. However, there is presumably better permeability andesite(sections#1-11 in photo)and andesitic tuff(sections#11-15 in below 457.2m if a deeper,hotter aquifer exists. photo). 849 Kolker,et al. _ n OSA, II 6igSs- 5ig f 597 . 4111111411111014111011414 Oa* \ ' ''.' ... . ,,i:','"- N' ' '' l'''');:: 11..:1.7 '''''1.52 C'''' a Figure 7.Core box showing the productive interval from TG2(dark sec- Figure 8.Fractured zone from 56.39m-56.7m in well TG4.Fractures are tions).Hot water at 359°F issued from a fractured and highly vesicular top filled with amorphous calcite,epidote, and sulfides(pyrite,arsenopyrite, of a basalt flow(sections#11-15 in photo).Note the darker color of the and possibly cinnabar). productive interval is because the rock remained wet for hours after core was pulled.Also note the mineralized subvertical vein in the rock just the hill to the SW,and lineations down-valley to the SW through above the productive interval. the alluvial fans.A number of brecciated zones were observed in TG4(Figure 9),but most were"sealed"with secondary mineral epidote at depths below—187m . The subvertical fractures were deposits and therefore probably do not represent active faults. very small(1-2 mm)and almost always mineralized with calcite and/or laumontite. Secondary minerals in TG2 included abundant calcite,chlo- rite,laumontite and other zeolites,unidentified clays, secondary ,, quartz,and sulfides(pyrite and arsenopyrite,rare cinnabar).Rare silica deposits were observed.Hairline suvbertical fractures were • + y a -' ' ';°- , filled with laumontite or calcite. Above —177.1m, the vugs in - ' +' ' w;'k . } -'.a vesicular portions of the flows were filled with a combination of 4 ,sr ,-- ;fi• % ' '1, >`; calcite and chlorite. Between —177.1m and —216.4m, the vugs p' - i .,-.01, r- „ '' in vesicular portions of the flows were filled with a combination _ :, `k: - of calcite,chlorite,epidote,and rare laumontite.The productive - . -' fracture at 178.31-178.92m had calcite,laumontite,chlorite,epi- dote, arsenopyrite, and cinnabar. Within the productive fracture and some vesicles below 177.1m,epidote displayed an interest- ing morphology, with radiating euhedral crystals nucleating on top of chlorite vein fill.Additional mineralized zones occurred at 210.3m and 214.9m,though the fractures in these zones did not appear to support large-volume fluid flow. Epidote and adularia were observed below 216.41m,though pyrite and other sulfides, Figure 9.Brecciated fracture zone with secondary calcite deposit from a and chlorite,continued below this zone. depth of 64.92m in TG4. Alteration minerals occurred interstitially, in fractures, in vesscles, and in contact zones and the tops of new flows. TG-4 Geothermal Fluid Sampling and Geochemistry was nearly completely"sealed," losing almost all its secondary (fracture)permeability to hydrothermal mineralization.Figure 9 Three water samples were obtained from the exploratory shows an example of a relatively shallow fracture zone that has core holes. Two samples were obtained from well TG-2, with been sealed by hydrothermal mineralization. However,there are the first obtained from a fracture zone during well discharge. abundant high-temperature hydrothermal alteration minerals pres- This production zone was subsequently cased off,and a second ent in TG-4 core rocks, even at very shallow depths.A detailed flow test of the well obtained samples from production zones analysis of the hydrothermal mineralogy is presently being con- between 189.9m and 253.9m MD, which was the completion ducted but the results were not yet available at the time of writing. depth of the core hole. The second core hole,TG-4,completed Slickensides observed in well rocks could be related to a pos- at 457.2m MD,encountered poor permeability conditions,and sible range front fault on the SW side of the valley near well 4. a sample of the fluids in the wellbore was obtained by flowing This fault was identified from observations of terrace faulting up with an air assist. 850 Kolker, et al. Also in 2010,samples of steam condensate and non-condensi- 4. Only water was being produced from the fracture at ble gas were obtained from fumarolic manifestations at the head 178.31m-178.92m where the fluid enters the 11.43cm hole. of Hot Springs Bay Valley. These new chemical data augment previously available chemical data from samples of the hot springs The standard enthalpy formula was used to obtain the total and fumaroles that were collected in the 1980's and 1990's. A mass flow at the surface.Prittchett's formula,an empirical calcula- report with these data and updated geochemical interpretations of tion based on several geothermal field observations,predicts the the resource is being prepared at the time of writing. deliverability of a full sized production well completed to a similar depth as TG-2 (See Appendix B for calculations). The outcome Discussion and Analysis of Preliminary of these calculations was an extrapolated volume(in gallons per Drilling Results minute,or"GPM")for a production well.That number can be used to convert the GPM of the full sized well into MW using Ormat At the time of writing,only preliminary(unequilibrated)tern- conversion tables at 182°C.These conversion factors are for ORC perature gradient data is available for the Akutan TG wells.The units manufactured by Ormat,Inc.There are other manufacturers equilibrated temperature gradient data is expected to be available of ORC turbo generators but all conversion factors are similar. in May,2011. In all probability a production well similar to TG-2 would be a Nonetheless, it is likely that a resource with similar tem- well completed with 34cm,54.5 ppf,K-55 buttress casing so that peratures to those measured during the drilling of TG-2 could a 30cm downhole pump could be run in the casing and the well support planned development on Akutan Island TG-2 encountered would be pumped. Water(brine)would be pumped to the surface a shallow aquifer of 181.7 °C (359 °F) at very shallow depths and run through a Rankine cycle("ORC")turbo-generator. of 178 m (585 ft.)Well TG4 did not encounter much fluid flow, Pritchett's formula calculations yielded an extrapolated and there was no real permeability (no open fractures) beyond pumped capacity of the TG2 resource ranging from 465 to 820 —335.28m,corresponding to a slowing of the temperature gradient gallons per minute(1760L/min—3104L/min).Based on the Ormat at—304.8m'.However,the overall temperature gradient in TG4 is conversion tables and above assumptions, it is estimated that a anomalously high,indicating regional favorability for a develop- production well with the same flow characteristics as TG2 would able resource,and suggesting a deeper,hotter,aquifer is present. produce 1.34 MW if completed near to TG2 up to a maximum Indeed,it is possible that the impermeable formations encountered of 2.38 MW. between —274.3m and TD at 457.2m in TG4 represent a "clay cap"that sits above a deeper,hotter system,perhaps the"upflow" Conclusions resource.This interpretation correlates well with other data(e.g., MT resistivity data; see Kolker et al, 2010) which shows TG4 The 2010 exploratory drilling program was successful in just barely penetrating a zone of increased resistivity that could identifying a geothermal resource that would support the proposed represent the top of a geothermal aquifer.The upflow resource is development at Akutan.A resource of 181.67°C was discovered at estimated to be>220°C(>430°F). Alternatively or additionally, depths of less than 182.88m.Since volume could not be measured, the presence of high-temperature hydrothermal alteration minerals calculations based on empirical geothermal field observations were that do not correspond to downhole temperatures may suggest that used to predict the deliverability of a full sized production well there was a prior hot alteration period that has come and gone. completed to a similar depth as TG2.These calculations yielded This is not atypical of large-scale,active hydrothermal reservoirs an extrapolated pumped capacity of the TG2 resource ranging which often"self-seal"as the fluids fill all available fractures with from 1760-3104 Liters per minute for a single larger-diameter mineral deposits. The earlier episode of hydrothermal activity production well. This means that a single production well with could have produced hot springs reaching the present-day surface, the same flow characteristics as TG2 would produce 1.34 MW up because amethyst-filled vugs were observed as shallow as 6.lm in to a maximum of 2.38 MW.While the size of the outflow is not TG4.This interpretation would also account for the mercury and reliably constrained,the minimum size of outflow system appears boron anomalies in the soil that were measured near TG4 during to be about 1000 x 500 m and may be as large as—3500 x 1000 the 2009 geochemical survey. m based on magneto-telluric (MT) data. This suggests that the A prediction of productivity of a production well drilled and resource could support the drilling of multiple production wells, completed to a similar depth as TG-2 can be made based on the if necessary.Based on these assumptions,anywhere from 1 to 6 preliminary results from drilling.Calculations were made concern- production wells will be required, depending on the size of the ing the possible productivity of Akutan TG-2,with the following energy demand.One or more injection wells will also be required assumptions based on observations at the wellhead: by the project. 1. The well is making two-phase flow. Data from TG4 present some evidence for the possibility that even higher-temperature fluids exist at accessible depths 2. 190 liters/min was measured at the surface. in Hot Springs Bay Valley; this possibility will be explored by 3. A column of water from surface to the production zone at continued analysis of existing data,and during the drilling of the 178.31m-I78.92m. larger-diameter wells. 851 Elf :,-.7.: C co L_ 90:117:80 90:OE:80 90:61:80 90:80:80 90:L S:LO 90:917:L0 90:SE:LO 90:bZ:LO .- 90:E1:L0 .N 90 Z0 LO N H 90:15:90 Q 90:017:90 .L � 90�6Z�90 ail O 90:81:90 t 0 4111190:L0:90 ▪ 0 N 90:9S:SO ` 90:5b:50 90:1E:S0 H N GJ 90:EZ:SO H g 90:Z1:S0 =MO , 90:10:50 _O 0 90:05:170 LL Q o W 90:6£:170 O N E 90:8Z:b0 ia �` N In M 90Li170 CL ani al I- W i- 90:90:170 90:SS:E0 Qro = ca C 901717:E0 co N 90:EE:E0 90:ZZ:E0 p 90:11:E0 Ammeoci. '-� 90:00:E0 90:617 Z0 90:8E:Z0 90:LZ:ZO 90:91:Z0 90:50:Z0 } 90:17S:10 90:E17:TO 90:ZE:10 90:1Z:10 90:01:10 90:65:00 0 0 0 0 0 0 N i(3)ain;eiadwaj- L 0 inm d111- 1111 iI- o m '/ '/ IF ri 0 inN N o E o 3 Ift N f0 L t o. E "' l' fi V o I- c f0 i+ 3 Y a 0 0 ;: !N CO L 0 I I I I _ O 0 0 0 0 0 0 0 0 0 N N Cf l0 00 0 N Cr l0 (4) uoi�ena13 ,-1 ,-i ,-I c-I AGPTG4 AGPTG4 AGPTG4 AGPTG4 8/22 4:30 AM Survey 8/22 4:30 PM Survey 8/23 4:30 AM Survey 5/11/2011 Survey Run#1 Run#2 Run#3 One run Elevation Temperature(° Temperature(" Temperature(` Temperature(° Depth(ft) (ft) F) Depth(ft) F) Depth(ft) F) Depth(ft) Elevation(ft) F) 50 -69 71 50 69 50 71 20 -99 60.9 100 -19 159 100 165 100 169 40 -79 117.5 120 1 168 120 177 120 180 60 -59 166.9 140 21 176 140 184 140 188 80 -39 185.7 160 41 182 160 191 160 195 100 -19 195.7 180 61 187 180 195 180 199 120 1 204.8 200 81 188 200 196 200 200 140 21 212.9 220 101 197 220 205 220 209 160 41 220.2 240 121 202 240 209 240 213 180 61 223 260 141 205 260 213 260 216 200 81 226 280 161 209 280 216 280 219 220 101 228.3 300 181 212 300 220 300 223 240 121 230.7 320 201 216 320 223 320 227 260 141 233.3 340 221 221 340 228 340 231 280 161 236.1 360 241 225 360 231 360 234 300 181 239.4 380 261 228 380 234 380 238 320 201 242.9 400 281 232 400 239 400 242 340 221 246.8 420 301 237 420 244 420 246 360 241 250.1 440 321 241 440 247 440 251 380 261 254.3 460 341 245 460 251 460 254 400 281 257.7 480 361 249 480 255 480 258 420 301 261.6 500 381 253 500 259 500 262 440 321 265.1 520 401 257 520 263 520 266 460 341 268.7 540 421 261 540 266 540 270 480 361 272.3 560 441 264 560 270 560 273 500 381 275.7 580 461 268 580 273 580 276 520 401 278.8 600 481 273 600 278 600 280 540 421 281.9 620 501 276 620 281 620 283 560 441 284.9 640 521 279 640 284 640 286 580 461 287.6 660 541 282 660 287 660 289 600 481 290.3 680 561 285 680 289 680 292 620 501 292.7 700 581 288 700 292 700 294 640 521 295.1 720 601 291 720 294 720 297 660 541 297.4 740 621 293 740 297 740 299 680 561 299.7 760 641 295 760 299 760 301 700 581 301.5 780 661 297 780 301 780 303 720 601 303.5 800 681 299 800 302 800 305 740 621 305.3 820 701 300 820 304 800 306 760 641 306.9 840 721 303 840 306 820 308 780 661 308.4 860 741 305 860 307 840 308 800 681 309.9 880 761 306 880 309 860 309 820 701 311.4 900 781 308 900 310 880 311 840 721 312.7 920 801 309 920 312 900 312 860 741 313.8 940 821 310 940 313 920 313 880 761 314.9 960 841 312 960 314 940 314 900 781 316.1 980 861 313 980 316 960 316 920 801 317 1000 881 312 1000 315 980 317 940 821 318.1 1020 901 315 1020 318 1000 317 960 841 319.1 1040 921 316 1040 317 1020 319 980 861 319.9 1060 941 318 1060 319 1040 318 1000 881 320.8 1080 961 318 1080 320 1060 320 1020 901 321.4 1100 981 319 1100 321 1080 321 1040 921 321.8 1120 1001 320 1120 321 1100 322 1060 941 322.1 1140 1021 321 1140 322 1120 322 1080 961 322.5 1160 1041 322 1160 323 1140 323 1100 981 322.9 1180 1061 322 1180 323 1160 324 1120 1001 323.5 1200 1081 323 1200 324 1180 324 1140 1021 323.9 1220 1101 323 1220 324 1200 325 1160 1041 324.1 1240 1121 324 1240 325 1220 325 1180 1061 324.5 1260 1141 324 1260 325 1240 325 1200 1081 324.6 1280 1161 325 1280 326 1260 326 1220 1101 325.1 1300 1181 325 1300 326 1280 326 1240 1121 325.3 1320 1201 326 1320 326 1300 326 1260 1141 325.7 1340 1221 326 1340 326.6 1320 327 1280 1161 325.9 1360 1241 326 1360 326.7 1340 327 1300 1181 326.3 1380 1261 326 1380 326.9 1360 327.1 1320 1201 326.4 1400 1281 326.6 1400 327.2 1380 327.3 1340 1221 326.5 1420 1301, 326.8 1420 327.3 1400, 327.5 1360 1241 326.7 1440 1321 327 1440 327.4 1420 327.6 1380 1261 326.9 1460 1341 327.1 1460 327.4 1470 327.81 1400 1281 327.1 1470 1351 327.1 1470 327.81 1470 327.7 1420 1301 327.3 1468 1349 326.6 1470 326.9 1440 1321 327.3 1460 1341 327.3 1470 1351 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-4 Well Name: Hot Spring Bay Valley 4-Akutan Field: Hot Springs Bay Va County:Aleutians East State:AK Country: United States Report No: 1 Report For 09-Aug-10 Operator: City Of Akutan Rig: Major LF90 Spud Date: 11-Aug-10 Daily Cost/Mud($): --- Measured Depth(ft): 0 Drilling Days(act.): 0 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 0 Drilling Days(plan): 24 RKB Elevation(ft): 10.00 --- --- --- Proposed TD(ft): 1500 Days On Location: 1 Last BOP Test: --- --- --- Hole Made(ft)/Hrs: 0/0.0 Last Casing: Totals --- Average ROP(ft/hr): Next Casing: 6.625 at 30 Working Interest: Well Cost($): --- Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 4 Total: 18 Current Operations: Waiting on daylight. Planned Operations: Continue to move and rig up on wellsite 4. Toolpusher: Dave Griggs Wellsite Supervisors: Dan Darnell Tel No.: 1-907-444-1777 Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 8:00 20:00 12.00 0 MOB Began moving equipment from Wellsite 2 to Wellsite 4. Comments Began moving between wellsites. Rig Information Equipment Problems: Location Condition: Transport: _ _ Safety Information Meetings/Drills Time Description Safety 30 Safety meeting held with both crews First Aid: Medical: Lost Time Accidents: Days Since LTA: 0 ❑ BOP Test ❑ Crownamatic Check Printed: 09:17 14-Feb-14 R/MBase 7.0.2.114 Page: 1 of 1 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-4 Well Name: Hot Spring Bay Valley 4-Akutan Field: Hot Springs Bay Va County:Aleutians East State:AK Country: United States Report No: 2 Report For 10-Aug-10 Operator: City Of Akutan Rig: Major LF90 Spud Date: 11-Aug-10 Daily Cost/Mud($): --- Measured Depth(ft): 0 Drilling Days(act.): 0 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 0 Drilling Days(plan): 24 RKB Elevation(ft): 10.00 --- --- --- Proposed TD(ft): 1500 Days On Location: 2 Last BOP Test: --- --- --- Hole Made(ft)/Hrs: 0/0.0 Last Casing: Totals --- --- Average ROP(ft/hr): Next Casing: 6.625 at 30 Working Interest: Well Cost($): --- Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 4 Total: 18 Current Operations: Waiting on daylight. Planned Operations: Continue to move and rig up on AGP TG-4 location Toolpusher: Dave Griggs Wellsite Supervisors: Dan Darnell Tel No.: 1-907-444-1777 Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 8:00 20:00 12.00 0 MOB Rig Move,Move equipment from AGP TG-2 and rig up on AGP TG-4 location, Comments Continued moving and rigging up. Rig Information Equipment Problems: Belt on Light Plant Location Condition: Transport: Safety Information Meetings/Drills Time Description Safety 30 Safety meeting held with both crews First Aid: Medical: Lost Time Accidents: Days Since LTA: 1 ❑ BOP Test ❑ Crownamatic Check Weather Information Sky Condition: Cloudy/Rain Visibility: Air Temperature: Bar.Pressure: Wind Speed/Dir: / Wind Gusts: Printed. 09:17 14-Feb-14 R/MBase 7.0.2.114 Page: 1 of 1 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-4 Well Name: Hot Spring Bay Valley 4-Akutan Field: Hot Springs Bay VE County:Aleutians East State:AK Country: United States Report No: 3 Report For 11-Aug-10 Operator: City Of Akutan Rig: Major LF90 Spud Date: 11-Aug-10 Daily Cost/Mud($): --- Measured Depth(ft): 38 Drilling Days(act.): 1 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 38 Drilling Days(plan): 24 RKB Elevation(ft): 10.00 --- --- --- Proposed TD(ft): 1500 Days On Location: 3 Last BOP Test: --- --- --- Hole Made(ft)/Hrs: 38/5.5 Last Casing: Totals --- --- Average ROP(ft/hr): 6.91 Next Casing: 6.625 at 30 Working Interest: Well Cost($): --- Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 4 Total: 18 Current Operations: Continued opening hole 7 1/2"to 9-7/8". Planned Operations: Finish opening hole. Run and cement 6-5/8"casing. Toolpusher: Dave Griggs Wellsite Supervisors: Dan Darnell Tel No.: 1-907-444-1777 Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 8:00 14:30 6.50 0 RIGU Rigged up on South Elbow wellsite and conducted prespud meeting. 14:30 20:00 5.50 38 DRIL Cored 5-1/2"hole f/5't/38'.Circ and POH. 20:00 22:00 2.00 38 OPEN Opened hole from 5-1/2"to 7-1/2" f/5't/38'.Circ and POH. 22:00 0:00 2.00 38 OPEN Opened hole from 7-1/2"to 9-7/8" f/5't/27'. Management Summary Mud pumps packing off due to sand. Mud Information % Gels Temp Mud Density Vis PV YP Filt. Cake pH/ES Solids Oil Water Sand LGS Chlor. Cal. 10s 10m 30m In Out Loss 11-Aug-10 22:00 60 Bit/BHA/Workstring Information Depth This Run R.O.P. Mud Pump No Run Make Model Diam In Dist Hrs Avg Max WOB RPM Torque Wt Flow Press J.Vel P.Drp HHP JIF 1 1 FORDIF 5.500 5 33 5.5 6.0 8 70 150 Jets: Out: 38 Grade: Cutter: / Dull / Wear: Brgs: Gge: Pull: 2 1 B HUGE GT-1 7.500 5 33 2 16.5 150 8 70 150 Jets: 18 18 18 Out: 38 Grade: Cutter: 1 /1 Dull NO/NO Wear:A Brgs: E Gge: 1 Pull: OTH 3 1 B HUGE GT-1 9.875 5 22 1 22.0 8 70 150 Jets: 18 18 18 Out: 38 Grade: Cutter: 2/2 Dull NO/NO Wear:A Brgs: E Gge: 1 Pull: OTH Drilling Parameters Depth(ft) ROP(ft/hr) WOB(lbs) RPM Torque(ft lbs) Flow(gals/min) Pressure From To Avg Max Avg Max Avg Max Avg Max Avg Max (psi) 0 27 5.0 10.0 150 250 Comments: Cored 5 1/2"pilot hole fallowed by drilling a 7 1/2"hole and then opening the 7 1/2"to 9 7/8"hole f/5'to 27'@00:00 hrs Rig Information Equipment Problems: Location Condition: Transport: Safety Information Meetings/Drills Time Description Safety 30 Prespud Meeting First Aid: Medical: Lost Time Accidents: Days Since LTA: 2 ❑ BOP Test ❑ Crownamatic Check Printed: 09:17 14-Feb-14 R/MBase 7.0.2.114 Page: 1 of 2 Daily Drilling Report Geothermal Resource Group 110 Well ID: AGP TGA Well Name: Hot Spring Bay Valley 4-Akutan Field: Hot Springs Bay Va County:Aleutians East State:AK Country: United States Report No: 3 Report For 11-Aug-10 Weather Information Sky Condition: Rain/Rain/Rain Visibility: Air Temperature: Bar.Pressure: Wind Speed/Dir: / Wind Gusts: Comments: LELS in cellar are checked twice every day Printed: 09:17 14-Feb-14 RIMBase 7.0.2.114 Page:2 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-4 Well Name: Hot Spring Bay Valley 4-Akutan Field: Hot Springs Bay VE County:Aleutians East State:AK Country: United States Report No: 4 Report For 12-Aug-10 Operator: City Of Akutan Rig: Major LF90 Spud Date: 11-Aug-10 Daily Cost/Mud($): --- Measured Depth(ft): 38 Drilling Days(act.): 2 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 38 Drilling Days(plan): 24 RKB Elevation(ft): 5.00 --- --- --- Proposed TD(ft): 1500 Days On Location: 4 Last BOP Test: --- --- --- Hole Made(ft)/Hrs: 0/0.0 Last Casing: 6.625 at 38 Totals --- --- Average ROP(ft/hr): Next Casing: 4.500 at 150 Working Interest: Well Cost($): --- Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 4 Total: 18 Current Operations: WOC. Installed 6-5/8'riser,3"flow line and fill up line. RIH and tagged TOC @ 34'.Cleaned out cement and cored ahead f/38'@ 06:00 hr's. Planned Operations: Continue to core 5-1/2"hole to casing point. Toolpusher: Dave Griggs Wellsite Supervisors: Dan Darnell Tel No.: 1-907-444-1777 Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 12:00 12.00 38 OPEN Opened hole w/9-7/8"bit f/27't/38'. 12:00 12:30 0.50 38 CIRC Circ and conditioned hole for conductor. 12:30 13:00 0.50 38 TRPO POH&L/D rotary tools. 13:00 14:00 1.00 38 CASE Ran 33'of 6-5/8"24#K55 as conductor with bottom of pipe @ 38'. 14:00 15:00 1.00 38 CMTP Pumped 3.4 bbls of 13.5#cement via tremie.Job required 100%excess.CIP @ 14:50 hrs. 15:00 0:00 9.00 38 WOC WOC, Comments Finished opening hole to 9-1/8". Set and cemented 6-5/8"conductor. WOC. Casingllubular Information Type Size Top MD Top TVD Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.625 5 5 38 38 COND 10.000 Mud Information % Gels Temp Mud Density Vis PV YP Filt. Cake pH/ES Solids Oil Water Sand LGS Chlor. Cal. 10s 10m 30m In Out Loss 12-Aug-10 04:00 8.40 55 65 65 Bit/BHAlWorkstring Information Depth This Run R.O.P. Mud Pump No Run Make Model Diam In Dist Hrs Avg Max WOB RPM Torque Wt Flow Press J.Vel P.Drp HHP JIF 3 1 B HUGE GT-1 9.875 5 33 13 2.5 60 8 70 150 30 7 0 9 Jets: 18 18 18 Out: 38 Grade: Cutter: 2/2 Dull NO/NO Wear:A Brgs: E Gge: 1 Pull: OTH _ Drilling Parameters Depth(ft) ROP(ft/hr) WOB(lbs) RPM Torque(ft lbs) Flow(gals/min) Pressure From To Avg Max Avg Max Avg Max Avg Max Avg Max (psi) 27 38 2.0 5.0 60 65 70 70 150 Annular Velocity: Drill Collars: 576.2 Drill Pipe: 576.2 Comments: Opened hole f/7 1/2"to 9 7/8"f/27'to 38' Rig Information Equipment Problems: Need fan belt on light Location Condition: good Transport: poor Printed: 09:17 14-Feb-14 RIMBase 7.0.2.114 Page: 1 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-4 Well Name: Hot Spring Bay Valley 4-Akutan Field: Hot Springs Bay V� County:Aleutians East State:AK Country: United States Report No: 4 Report For 12-Aug-10 Inventory Bulk Used This Received This Bulk Used This Received This Material Report Period Report Period Inventory Material Report Period Report Period Inventory BARITE 156 44 GEL 360 24 CaC 58 42 AQUA PAC 0 20 CEMENT 91 11 POLY VIS 31 5 TORKEASE 0 5 EZ-MUD 26 14 SODA ASH 2 98 DEFOAM14 0 5 DESCO CF 0 5 ZINC 0 1 CAUSTIC 0 6 Safety Information Meetings/Drills Time Description Safety 30 Safety meeting held with both crews First Aid: Medical: Lost Time Accidents: Days Since LTA: 3 ❑ BOP Test ❑ Crownamatic Check Weather Information Sky Condition: Rain/wind Visibility: Air Temperature: Bar.Pressure: Wind Speed/Dir: / Wind Gusts: Comments: LELS in cellar are checked twice every day Printed: 09:17 14-Feb-14 R/MBase 7.0.2.114 Page:2 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-4 Well Name: Hot Spring Bay Valley 4-Akutan Field: Hot Springs Bay W County:Aleutians East State:AK Country: United States Report No: 5 Report For 13-Aug-10 Operator: City Of Akutan Rig: Major LF90 Spud Date: 11-Aug-10 Daily Cost/Mud($): --- Measured Depth(ft): 168 Drilling Days(act.): 3 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 168 Drilling Days(plan): 24 RKB Elevation(ft): 5.00 --- --- --- Proposed TD(ft): 1500 Days On Location: 5 Last BOP Test: --- --- --- Hole Made(ft)/Hrs: 130/21.0 Last Casing: 6.625 at 38 Totals --- --- Average ROP(ft/hr): 6.19 Next Casing: 4.500 at 150 Working Interest: Well Cost($): --- Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 4 Total: 18 Current Operations: Cored 5-1/2"hole w/PQ rods f/168't1188'. Began losing 5 bbls @ 172'.Circulated until 06:00-pulled from sump. Prepare to set LC plug. Planned Operations: POH to remove bit and core barrel. RIH open ended and set 30'cmt LC plug @ 143'. Toolpusher: Dave Griggs Wellsite Supervisors: Dan Darnell Tel No.: 1-907-444-1777 Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 2:00 2.00 38 WOC WOC 2:00 21:30 19.50 157 DRIL Cored 5-1/2"hole f/38't/157'. Began losing 5 bbls/hr @ 143'. 21:30 22:30 1.00 157 CIRC Circ and checked for loss @ 157'. No loss. 22:30 0:00 1.50 168 DRIL Cored 5-1/2"hole f/157't/168'w/full returns. Comments WOC for conductor. Cored 5-1/2"hole f/38't/168'. Began losing 5 BPH at 143'. Casing/Tubular Information Type Size Top MD Top TVD Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.625 5 5 38 38 COND 10.000 Mud Information % Gels Temp Mud Density Vis PV YP Filt. Cake pH/ES Solids Oil Water Sand LGS Chlor. Cal. 10s 10m 30m In Out Loss 13-Aug-10 20:00 8.40 42 0 51 51 Bit/BHA/Workstring Information Depth This Run R.O.P. Mud Pump No Run Make Model Diam In Dist Hrs Avg Max WOB RPM Torque Wt Flow Press J.Vel P.Drp HHP JIF 1 2 FORDIF 5.500 33 130 22 5.9 12.0 0 1200 8 50 175 Jets: Out: 188 Grade: Cutter: / Dull / Wear: Brgs: Gge: Pull: Drilling Parameters Depth(ft) ROP(ft/hr) WOB(lbs) RPM Torque(ft lbs) Flow(gals/min) Pressure From To Avg Max Avg Max Avg Max Avg Max Avg Max (psi) 38 168 10.0 12.0 800 1200 35 50 175 Comments: Core 5 1/2"hole w/PQ rods,Core F/38'to 168'; Survey Information Survey Meas. Vertical Coordinates Type Depth Inc. Azimuth TVD Closure Section N-S E-W D.L.S. TOTCO 103.0 2.00 Rig Information Equipment Problems: Fixed light plant Location Condition: WET(good) Transport: Poor Printed: 09:17 14-Feb-14 RIMBase 7.0.2.114 Page: 1 of 2 Daily Drilling Report Geothermal Resource Group 0 Well ID: AGP TG-4 Well Name: Hot Spring Bay Valley 4-Akutan Field: Hot Springs Bay VE County: Aleutians East State:AK Country: United States Report No: 5 Report For 13-Aug-10 Inventory Bulk Used This Received This Bulk Used This Received This Material Report Period Report Period Inventory Material Report Period Report Period Inventory BARITE 44 GEL 4 20 CaC 42 AQUA PAC 20 CEMENT 11 POLY VIS 2 4 TORKEASE 5 EZ-MUD 14 SODA ASH 98 DEFOAM14 5 DESCO CF 5 ZINC 1 CAUSTIC 6 Safety Information Meetings/Drills Time Description Safety 30 Safety meeting held with both crews First Aid: Medical: Lost Time Accidents: Days Since LTA: 4 ❑ BOP Test ❑ Crownamatic Check Weather Information Sky Condition: Rain/Rain/Rain Visibility: Air Temperature: 39.0 degF Bar. Pressure: Wind Speed/Dir: 35/N Wind Gusts: 72 Comments: LELS in cellar are checked twice every day,We are getting alot of rain,Trying to keep the sump down, Printed: 09:17 14-Feb-14 R/MBase 7.0.2.114 Page:2 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-4 Well Name: Hot Spring Bay Valley 4-Akutan Field: Hot Springs Bay W County:Aleutians East State:AK Country: United States Report No: 6 Report For 14-Aug-10 Operator: City Of Akutan Rig: Major LF90 Spud Date: 11-Aug-10 Daily Cost/Mud($): --- Measured Depth(ft): 188 Drilling Days(act.): 4 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 188 Drilling Days(plan): 24 RKB Elevation(ft): 5.00 --- --- --- Proposed TD(ft): 1500 Days On Location: 6 Last BOP Test: --- --- --- Hole Made(ft)/Hrs: 20/2.0 Last Casing: 6.625 at 38 Totals --- --- Average ROP(ft/hr): 10.0 Next Casing: 4.500 at 150 Working Interest: Well Cost($): --- Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 4 Total: 18 Current Operations: Circulated and conditioned hole for casing POH.RIH with HWT(4.5")casing-float collar between first and second joint, casing shoe at 176'. Circulated casing with no loss. Planned Operations: Cement HWT casing. Install wellhead and nipple up BOPE. Toolpusher: Dave Griggs Wellsite Supervisors: Dan Darnell Tel No.: 1-907-444-1777 1 Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 2:00 2.00 188 DRIL Cored 5-1/2"hole f/168't/188'w/7-10 bph loss. 2:00 8:00 6.00 188 CIRC Circulated and pumped sump down. 8:00 9:00 1.00 188 TRPO POH&UD bit&core barrel. 9:00 9:30 0.50 188 TRPI RIH OEDP to 140'. 9:30 10:00 0.50 188 CMTPL Rig up cementing equipment. 10:00 10:30 0.50 188 CMTPL Mixed 1 bbl of 13.5#premium cement as lost circulation plug and spotted at 140'. CIP @ 10:30 hrs. 10:30 18:00 7.50 188 WOC WOC. Made up tools while waiting. 18:00 19:00 1.00 188 TRPI RIH&Tag TOC @ 120'. 19:00 22:30 3.50 188 CMTD Cleaned out cement f/120't/172'. Fell out of cement at 172'. Ran in hole to 188'. 22:30 0:00 1.50 188 CIRC Circulated and conditioned hole with full returns. Comments Cored 5-1/2"hole f/168't/188'with 5-7 bph losses. Set 1 bbl lost circulation plug and waited on cement. Cleaned out cement f/120'and circulated hole with no loss. Casing/Tubular Information Type Size Top MD Top TVD Bottom MD Bottom ND Hole Section Avg OH Diam LOT FULL 6.625 5 5 38 38 COND 10.000 Mud Information cyo Gels Temp Mud Density Vis PV YP Filt. Cake pH/ES Solids Oil Water Sand LGS Chlor. Cal. 10s 10m 30m In Out Loss 14-Aug-10 23:00 Sample from Mud Pits 8.40 44 9 72 75 Bit/BHA/Workstring Information Depth This Run R.O.P. Mud Pump No Run Make Model Diam In Dist Hrs Avg Max WOB RPM Torque Wt Flow Press J.Vel P.Drp HHP JIF 1 2 FORDIF 5.500 33 150 24 6.2 9 45 150 Jets: Out: 188 Grade: Cutter: / Dull / Wear: Brgs: Gge: Pull: Drilling Parameters Depth(ft) ROP(ft/hr) WOB(lbs) RPM Torque(ft lbs) Flow(gals/min) Pressure From To Avg Max Avg Max Avg Max Avg Max Avg Max (psi) 168 188 10.0 10.0 800 1100 45 45 120 Annular Velocity: Drill Collars: 404.5 Drill Pipe: 404.5 Comments: Cored 5-1/2"hole with partial losses. Rig Information Equipment Problems: None Location Condition: Wet,muddy. Transport: poor Printed: 09:17 14-Feb-14 R/MBase 7.0.2.114 Page: 1 of 2 Daily Drilling Report Geothermal Resource Group 640 Well ID: AGP TG-4 Well Name: Hot Spring Bay Valley 4-Akutan Field: Hot Springs Bay Vs County:Aleutians East State:AK Country: United States Report No: 6 Report For 14-Aug-10 Inventory Bulk Used This Received This Bulk Used This Received This Material Report Period Report Period Inventory Material Report Period Report Period Inventory BARITE 44 GEL 4 16 CaC 42 AQUA PAC 1 19 CEMENT 7 4 POLY VIS 0.25 3.75 TORKEASE 5 EZ-MUD 14 SODA ASH 98 DEFOAM14 5 DESCO CF 5 ZINC 1 CAUSTIC 0.25 5.75 Safety Information Meetings/Drills Time Description Safety 30 Crews held pre-tour safety meetings. First Aid: Medical: Lost Time Accidents: Days Since LTA: 5 ❑ BOP Test ❑ Crownamatic Check Weather Information Sky Condition: Cloudy Visibility: Air Temperature: 44.0 degF Bar.Pressure: Wind Speed/Dir: / Wind Gusts: Comments: LELS in cellar are checked twice every day Printed: 09:17 14-Feb-14 R/MBase 7.0.2.114 Page:2 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG 4 Well Name: Hot Spring Bay Valley 4-Akutan Field: Hot Springs Bay Ve County:Aleutians East State:AK Country: United States Report No: 7 Report For 15-Aug-10 Operator: City Of Akutan Rig: Major LF90 Spud Date: 11-Aug-10 Daily Cost/Mud($): --- Measured Depth(ft): 188 Drilling Days(act.): 5 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 188 Drilling Days(plan): 24 RKB Elevation(ft): 5.00 --- --- --- Proposed TD(ft): 1500 Days On Location: 7 Last BOP Test: --- --- --- Hole Made(ft)/Hrs: 0/0.0 Last Casing: 4.500 at 186 Shoe Test(lbs/gal): 832.00 Totals --- --- Average ROP(ft/hr): Next Casing: 3.500 at 600 Working Interest: Well Cost($): --- Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 4 Total: 18 Current Operations: Nippled up BOPE,function testing @ 06:00 hr's. Planned Operations: Test BOPE.Make up HQ 3.87"bit and core barrel and run in hole to the TOC. Circ and test csg. Clean out csg and drill 20' of new hole. Perform formation integrity test to.625 psi gradient and drill ahead t/600'. Toolpusher: Dave Griggs Wellsite Supervisors: Dan Darnell Tel No.: 1-907-444-1777 Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 3:00 3.00 188 CIRC Circ and conditioned hole @ 176'. 3:00 4:00 1.00 188 TRPO POH and L/D core barrel and bit. 4:00 6:00 2.00 188 CASE Ran 18 joints/186'of 4-1/2"11.2#4130 HWT casing with float collar between first and second jt. Bakerlocked each joint. Casing shoe at 186'. 6:00 11:30 5.50 188 CIRC Circulated casing and conditioned for cement. 11:30 13:00 1.50 188 WOE Waited for cement to be unloaded at the dock and heli over. X 13:00 14:30 1.50 188 CMTP Mixed and displaced 4.0 bbls of 13.5#premium cement with 30%silica flour, using 100%excess.Good cement returns to surface. Bumped plug with 500 psi. CIP @ 14:30 hrs. 14:30 22:30 8.00 188 WOC WOC. Removed riser. 22:30 0:00 1.50 188 OTHER Slacked off and layed down landing joint. Installed weld ring and began nippling up well head.TOC was 1 ft down from surface. Comments Circulated and conditioned hole. Ran 186'of 4.5"11.2#HWT 4130 casing with shoe at 186'. Cemented casing with good cement to surface. WOC. Layed out riser and began nippling up wellhead and BOPE. Casing/Tubular Information Type Size Top MD Top TVD Bottom MD Bottom ND Hole Section Avg OH Diam LOT FULL 6.625 5 5 38 38 COND 10.000 FULL 4.500 5 5 186 186 SURF 5.500 832.00 Mud Information Gels Temp Mud Density Vis PV YP Filt. Cake pH/ES Solids Oil Water Sand LGS Chlor. Cal. 10s 10m 30m In Out Loss 15-Aug-10 22:00 8.40 42 Bit/BHA/Workstring Information Depth This Run R.O.P. Mud Pump No Run Make Model Diam In Dist Hrs Avg Max WOB RPM Torque Wt Flow Press J.Vel P.Drp HHP JIF 1 2 FORDI. 5.500 33 150 24 Jets: Out: 188 Grade: Cutter: / Dull / Wear: Brgs: Gge: Pull: Survey Information Survey Meas. Vertical Coordinates Type Depth Inc. Azimuth TVD Closure Section N-S E-W D.L.S. TOTCO 208.0 0.75 Rig Information Equipment Problems: None Location Condition: Wet,muddy. Transport: poor Printed. 09:17 14-Feb-14 RIMBase 7.0.2.114 Page: 1 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-4 Well Name: Hot Spring Bay Valley 4-Akutan Field: Hot Springs Bay W County:Aleutians East State:AK Country: United States Report No: 7 Report For 15-Aug-10 Inventory Bulk Used This Received This Bulk Used This Received This Material Report Period Report Period Inventory Material Report Period Report Period Inventory BARITE 44 GEL 16 CaC 42 AQUA PAC 19 CEMENT 4 POLY VIS 3.75 TORKEASE 5 EZ-MUD 14 SODA ASH 98 DEFOAM14 5 DESCO CF 5 ZINC 1 CAUSTIC 5.75 Safety Information Meetings/Drills Time Description Safety 30 Crews held pre-tour safety meeting First Aid: Medical: Lost Time Accidents: Days Since LTA: 6 ❑ BOP Test ❑ Crownamatic Check Weather Information Sky Condition: Rain/Rain/and more Rain Visibility: Air Temperature: Bar.Pressure: Wind Speed/Dir: / Wind Gusts: Comments: LELS in cellar are checked twice every day Printed: 09:17 14-Feb-14 RIMBase 7.0.2.114 Page:2 of 2 Daily Drilling Report Geothermal Resource Group litWell ID: AGP TG-4 Well Name: Hot Spring Bay Valley 4-Akutan Field: Hot Springs Bay Va County:Aleutians East State:AK Country: United States Report No: 8 - Report For 16-Aug-10 Operator: City Of Akutan Rig: Major LF90 Spud Date: 11-Aug-10 Daily Cost/Mud($): --- ' Measured Depth(ft): 301 Drilling Days(act.): 6 Well Bore: Original Well Bore AFE No. AFE($) Actual($) 'Vertical Depth(ft): 301 Drilling Days(plan): 24 RKB Elevation(ft): 5.00 --- --- --- Proposed TD(ft): 1500 Days On Location: 8 Last BOP Test: 16-Aug-10 --- --- --- Hole Made(ft)/Hrs: 113/6.5 Last Casing: 4.500 at 186 Shoe Test(lbs/gal): 832.00 Totals --- --- Average ROP(ft/hr): 17.38 Next Casing: 3.500 at 600 Working Interest: Well Cost($): --- Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 4 Total: 18 Current Operations: Cored 3.780"hole f/301'to 410',flow line temp 101 deg F @ 06:00 hr's Planned Operations: Continue to Core and Survey Toolpusher: Dave Griggs Wellsite Supervisors: Dan Darnell Tel No.: 1-907-444-1777 Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 8:00 8.00 188 BOPNU Nipple up BOPE and function test. 8:00 11:00 3.00 188 BOPT Test BOPE and valve's.Low-200,High-750,Test Good 11:00 11:30 0.50 188 TRPI Make up 3.780 bit and core barrel,Pick up HQ rods and RIH,Tagged TOC @ 166' 11:30 12:00 0.50 188 SURV Run temp survey @ 166'MRT 180 deg F 12:00 15:30 3.50 188 CMTD Clean out cement and wiper plug to the float collar @ 176',continue cleaning out cement f/176'to 188' 15:30 17:30 2.00 208 DRIL Core 3.780 hole f/188'to 208' 17:30 18:00 0.50 208 CIRC Circ hole clean @ 208'and pull up in shoe @ 186' 18:00 19:00 1.00 208 FIT Perform FIT to 12 ppg,Pumped a total of 3 gals @ 1.5 gal a min to 40 psi,Held for 15 min,(test good) 19:00 19:30 0.50 208 SURV Run survey @ 208',-.75 deg, MRT 85 deg F 19:30 0:00 4.50 301 DRIL Core 3.780"hole f/208'to 301'flow line temp 95 deg F Casing/Tubular Information Type Size Top MD Top TVD Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.625 5 5 38 38 COND 10.000 FULL 4.500 5 5 186 186 SURF 5.500 832.00 Mud Information % Gels Temp Mud Density Vis PV YP Filt. Cake pH/ES Solids Oil Water Sand LGS Chlor. Cal. 10s 10m 30m In Out Loss 16-Aug-10 22:00 8.40 44 8 0 52 95 Bit/BHA/Workstring Information Depth This Run R.O.P. Mud Pump No Run Make Model Diam In Dist Hrs Avg Max WOB RPM Torque Wt Flow Press J.Vel P.Drp HHP JIF 4 1 ADT 8DM 3.780 188 113 6.5 17.4 22.0 1200 8 45 200 Jets: Out: 510 Grade: Cutter: / Dull / Wear: Brgs: Gge: Pull: Drilling Parameters Depth(ft) ROP(ft/hr) WOB(lbs) RPM Torque(ft lbs) Flow(gals/min) Pressure From To _ Avg Max Avg Max Avg Max Avg Max Avg Max (psi) 188 301 10.0 20.0 1000 1200 35 45 200 Annular Velocity: Drill Collars: 404.0 Drill Pipe: 404.0 Comments: Cored 3.780"hole f/208'to 301'w/full return's Survey Information Survey Meas. Vertical Coordinates Type Depth Inc. Azimuth TVD Closure Section N-S E-W D.L.S. TOTCO 301.0 2.50 TOTCO 403.0 2.50 Printed: 09:17 14-Feb-14 RIMBase 7.0.2.114 Page: 1 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-4 Well Name: Hot Spring Bay Valley 4-Akutan Field: Hot Springs Bay Vs County:Aleutians East State:AK Country: United States Report No: 8 Report For 16-Aug-10 Rig Information Equipment Problems: None Location Condition: Wet,muddy. Transport: poor Inventory Bulk Used This Received This Bulk Used This Received This Material Report Period Report Period Inventory Material Report Period Report Period Inventory DEFOAM14 5 DESCO CF 5 ZINC 1 CAUSTIC 5.75 BARITE 44 GEL 16 CaC 42 AQUA PAC 19 CEMENT 4 POLY VIS 1 2.75 TORKEASE 0.5 4.5 EZ-MUD 14 SODA ASH 98 Safety Information Meetings/Drills Time Description Safety 30 Crews held pre-tour safety meeting First Aid: Medical: Lost Time Accidents: Days Since LTA: 7 BOP Test ❑ Crownamatic Check Weather Information Sky Condition: Cloudy/Rain Visibility: 3 Air Temperature: 46.0 degF Bar.Pressure: Wind Speed/Dir: / Wind Gusts: 35 Comments: LELS in cellar are checked twice every day Printed: 09:17 14-Feb-14 R/MBase 7.0.2.114 Page:2 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-4 Well Name: Hot Spring Bay Valley 4-Akutan Field: Hot Springs Bay VE County:Aleutians East State:AK Country: United States Report No: 9 Report For 17-Aug-10 Operator: City Of Akutan Rig: Major LF90 Spud Date: 11-Aug-10 Daily Cost/Mud($): --- Measured Depth(ft): 547 Drilling Days(act.): 7 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 547 Drilling Days(plan): 24 RKB Elevation(ft): 5.00 --- --- --- Proposed TD(ft): 1500 Days On Location: 9 Last BOP Test: 16-Aug-10 --- --- --- Hole Made(ft)/Hrs: 246/16.25 Last Casing: 4.500 at 186 Shoe Test(lbs/gal): 832.00 Totals --- --- Average ROP(ft/hr): 15.14 Next Casing: 3.500 at 600 Working Interest: Well Cost($): --- Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 4 Total: 18 Current Operations: Cored 3.78"hole f/547't/600'.Circ and survey @ 600'.POH&L/D HQ rods.Made up 3-1/2"HQ parallel wall csg with float collar between first and second joint. Running casing at @ 06:00 hrs. Planned Operations: Run csg and cement.WOC. Toolpusher: Dave Griggs Wellsite Supervisors: Dan Darnell Tel No.: 1-907-444-1777 Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 11:30 11.50 503 DRIL Cored 3.78"hole f/301'U 503'with full returns. 11:30 12:30 1.00 503 SURV Survey @ 503'2 deg 12:30 13:30 1.00 510 DRIL Cored 3.78"hole f/503't/510'with full returns. 13:30 15:30 2.00 510 TRPO POH to change bit. X 15:30 17:00 1.50 510 TRPI M/U bit#5 and RIH to 510'. X 17:00 19:00 2.00 527 DRIL Cored 3.78"hole f/510't1527'with full returns. Core barrel became stuck. 19:00 20:30 1.50 527 TRPO POH and recovered core. Repaired inner barrel. X 20:30 21:45 1.25 527 TRPI RIH to 527'. X 21:45 22:15 0.50 527 CIRC Circ and cooled well @ 527'. 22:15 0:00 1.75 547 DRIL Cored 3.78"hole f/527't/547'with full returns. Comments Cored 3.78"hole f/301't/503'.Tripped for bit. Cored 3.78"hole f/503't/510'. Tripped to retrieve stuck inner barrel. Cored 3.78"hole f/527 U547'. Casing/Tubular Information Type Size Top MD Top TVD Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.625 5 5 38 38 COND 10.000 FULL 4.500 5 5 186 186 SURF 5.500 832.00 Mud Information % Gels Temp Mud Density Vis PV YP Filt. Cake pH/ES Solids Oil Water Sand LGS Chlor. Cal. 10s 10m 30m In Out Loss 17-Aug-10 22:00 8.40 44 76 101 Bit/BHA/Workstring Information Depth This Run R.O.P. Mud Pump No Run Make Model Diam In Dist Hrs Avg Max WOB RPM Torque Wt Flow Press J.Vel P.Drp HHP JIF 4 1 ADT 8DM 3.780 188 313 19 16.5 22.0 1200 8 45 210 Jets: Out: 510 Grade: Cutter: / Dull / Wear: Brgs: Gge: Pull: 5 1 FORDIF Volcan 3.780 510 37 4 9.2 15.0 1200 8 45 210 Jets: Out: 600 Grade: Cutter: / Dull / Wear: Brgs: Gge: Pull: Drilling Parameters Depth(ft) ROP(ft/hr) WOB(lbs) RPM Torque(ft lbs) Flow(gals/min) Pressure From To Avg Max Avg Max Avg Max Avg Max Avg Max (psi) 301 547 10.0 20.0 1000 1200 35 45 210 Annular Velocity: Drill Collars: 404.0 Drill Pipe: 404.0 Comments: Core 3.780"hole f/301'to 547' Printed: 09:17 14-Feb-14 R/MBase 7.0.2.114 Page: 1 of 2 Daily Drilling Report Geothermal Resource Group litWell ID: AGP TG-4 Well Name: Hot Spring Bay Valley 4-Akutan Field: Hot Springs Bay Ve County:Aleutians East State:AK Country: United States Report No: 9 Report For 17-Aug-10 Survey Information Survey Meas. Vertical Coordinates Type Depth Inc. Azimuth TVD Closure Section N-S E-W D.L.S. TOTCO 503.0 2.00 Rig Information Equipment Problems: None Location Condition: Wet,muddy. Transport: poor Inventory Bulk Used This Received This Bulk Used This Received This Material Report Period Report Period Inventory Material Report Period Report Period Inventory DEFOAM14 5 DESCO CF 5 ZINC 1 CAUSTIC 5.75 BARITE 44 GEL 16 CaC 42 AQUA PAC 19 CEMENT 4 POLY VIS 1 1.75 TORKEASE 4.5 EZ-MUD 14 SODA ASH 98 Safety Information Meetings/Drills Time Description Safety 30 Crews held pre-tour safety meeting First Aid: Medical: Lost Time Accidents: Days Since LTA: 8 ❑ BOP Test ❑ Crownamatic Check Weather Information Sky Condition: Cloudy Visibility: Air Temperature: Bar.Pressure: Wind Speed/Dir: / Wind Gusts: Comments: LELS in cellar are checked twice every day Printed: 09:17 14-Feb-14 RIMBase 7.0.2.114 Page:2 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-4 Well Name: Hot Spring Bay Valley 4-Akutan Field: Hot Springs Bay Va County:Aleutians East State:AK Country: United States Report No: 10 Report For 18-Aug-10 Operator: City Of Akutan Rig: Major LF90 Spud Date: 11-Aug-10 Daily Cost/Mud($): Measured Depth(ft): 600 Drilling Days(act.): 8 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 600 Drilling Days(plan): 24 RKB Elevation(ft): 5.00 --- --- --- Proposed TD(ft): 1500 Days On Location: 10 Last BOP Test: 16-Aug-10 --- --- --- Hole Made(ft)/Hrs: 53/3.0 Last Casing: 3.500 at 596 Shoe Test(lbs/gal): 1,012.00 Totals --- --- Average ROP(ft/hr): 17.67 Next Casing: 1.660 at 1,500 Working Interest: Well Cost($): --- Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 4 Total: 18 Current Operations: Slack off and Unscrew top jt,Close master valve and test csg to 750 psi,Test good,Open master valve and install test plug,Test BOPE and valves.low-200-High 750,M/U 2.98 core bit and pick up NQ rods and RIH @ 06:00 hr;s Planned Operations: Run in hole w/NQ and tag TOC,Rig up and run TP log,Clean out CMT,FC and drill 20'of new hole to 620',Conduct leak off test @ 620',Core 2.98 hole f/620' Toolpusher: Dave Griggs Wellsite Supervisors: Dan Darnell Tel No.: 1-907-444-1777 Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 3:00 3.00 600 DRIL Cored 3.78"hole f/547'to 600'with full returns.flow line temp 107 deg F 3:00 4:00 1.00 600 SURV Circ and survey©600' 2.5 deg 4:00 5:30 1.50 600 TRPO POOH laying out HQ rods f/600' 5:30 6:00 0.50 600 CASE Rig up to run 3 1/2"csg 6:00 12:30 6.50 600 CASE Run 59 jts of 3-1/2"HQ parallel wall csg with float collar between the first and second joint to 596' 12:30 15:30 3.00 600 CIRC Circ and condition hole.Flow line temp 107.9 deg F 15:30 16:30 1.00 600 CMTP Mix and pump 13.5#cement w/100%excess,Cement to surface,CIP @ 16:30 16:30 0:00 7.50 600 WOC WOC,Lift and clean around well head and stack. Casing/Tubular Information Type Size Top MD Top TVD Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.625 5 5 38 38 COND 10.000 FULL 4.500 5 5 186 186 SURF 5.500 832.00 FULL 3.500 5 5 596 596 INTI 3.780 1012.00 Mud Information % Gels Temp Mud Density Vis PV YP Filt. Cake pH/ES Solids Oil Water Sand LGS Chlor. Cal. 10s 10m 30m In Out Loss 18-Aug-10 02:00 Sample from Mud Pits 8.40 44 9 0 72 107 Bit/BHA/Workstring Information Depth This Run R.O.P. Mud Pump No Run Make Model Diam In Dist Hrs Avg Max WOB RPM Torque Wt Flow Press J.Vel P.Drp HHP JIF 5 1 FORDIF Volcan 3.780 510 90 7 12.9 15.0 1100 8 35 210 Jets: Out: 600 Grade: Cutter: / Dull / Wear: Brgs: Gge: Pull: Drilling Parameters Depth(ft) ROP(ft/hr) WOB(lbs) RPM Torque(ft lbs) Flow(gals/min) Pressure From To Avg Max Avg Max Avg Max Avg Max Avg Max (psi) 547 600 10.0 15.0 1000 1200 35 45 210 Annular Velocity: Drill Collars: 404.0 Drill Pipe: 404.0 Comments: Cored 3.78"hole f/547'to 600'with full returns.flow line temp 107 deg F Survey Information Survey Meas. Vertical Coordinates Type Depth Inc. Azimuth TVD Closure Section N-S E-W D.L.S. TOTCO 600.0 2.00 Printed: 09:17 14-Feb-14 RIMBase 7.0.2.114 Page: 1 of 2 Daily Drilling Report Geothermal Resource Group X10 Well ID: AGP TG-4 Well Name: Hot Spring Bay Valley 4-Akutan Field: Hot Springs Bay Va County:Aleutians East State:AK Country: United States Report No: 10 Report For 18-Aug-10 Mud Log Information Depth(ft) TVD(ft) Gas(Units) Gas Drilling Pore Mud Shale ROP From To From To Avg Max at Depth Connect. Trip Exp. Press Dens. Dens. Shale Sand 547 600 Formation Name: Lithology: Rig Information Equipment Problems: None Location Condition: Wet,muddy. Transport: The inventory is whats on the rig only Inventory Bulk Used This Received This Bulk Used This Received This Material Report Period Report Period Inventory Material Report Period Report Period Inventory DEFOAM14 5 DESCO CF 0.5 4.5 ZINC 1 CAUSTIC 5.75 BARITE 44 GEL 6 10 CaC 42 AQUA PAC 19 CEMENT 34 35 5 POLY VIS 0.75 1 TORKEASE 4.5 EZ-MUD 14 SODA ASH 98 Safety Information Meetings/Drills Time Description Safety 30 Crews held pre-tour safety meeting First Aid: Medical: Lost Time Accidents: Days Since LTA: 9 ❑ BOP Test ❑ Crownamatic Check Weather Information Sky Condition: Visibility: Air Temperature: Bar.Pressure: Wind Speed/Dir: / Wind Gusts: Comments: LELS in cellar are checked twice every day Printed: 09:17 14-Feb-14 RIMBase 7.0.2.114 Page:2 of 2 Daily Drilling Report Geothermal Resource Group RGG Well ID: AGP TGA Well Name: Hot Spring Bay Valley 4-Akutan Field: Hot Springs Bay Va County:Aleutians East State:AK Country: United States Report No: 11 Report For 19-Aug-10 Operator: City Of Akutan Rig: Major LF90 Spud Date: 11-Aug-10 Daily Cost/Mud($): --- Measured Depth(ft): 793 Drilling Days(act.): 9 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 793 Drilling Days(plan): 24 RKB Elevation(ft): 5.00 --- --- --- Proposed TD(ft): 1500 Days On Location: 11 Last BOP Test: 19-Aug-10 --- --- --- Hole Made(ft)/Hrs: 193/8.5 Last Casing: 3.500 at 596 Shoe Test(lbs/gal): 1,012.00 Totals --- --- Average ROP(ft/hr): 22.71 Next Casing: 1.660 at 1,500 Working Interest: Well Cost($): --- Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 5 Total: 19 Current Operations: Cored 3.032"hole f/793't/923'w/full returns. Flow line temp= 105 deg F. 923'@ 06:00 hrs. Planned Operations: Continue to core 3.032 hole with surveys to 1500'. Toolpusher: Dave Griggs Wellsite Supervisors: Dan Darnell Tel No.: 1-907-444-1777 Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 1:00 1.00 600 WOC WOC. Nippled up BOP. 1:00 5:00 4.00 600 BOPT Tested annular preventer and valves to a low of 200 psi and high of 750 psi.Good tests. 5:00 5:30 0.50 600 OTHER Changed rod handling equipment over to NQ. 5:30 8:00 2.50 600 TRPI M/U 3.032" 8 D2 core bit and NQ core barrel and rods. RIH and tagged TOC @ 566'. 8:00 11:00 3.00 600 SURV Rigged up and ran PT survey tool to 544'. Bottom hole temp=265 deg F 11:00 11:30 0.50 600 CIRC Circ and cooled well @ 566'. 11:30 13:30 2.00 600 CMTD Cleaned out cement f/566'. 13:30 15:00 1.50 620 DRIL Cored new 3.032"hole f/600't/620'. 15:00 16:00 1.00 600 FIT Conducted leak off test. Pumped in 3/4 gal intervals to 596 psi surface pressure before halting test. Fracture Gradient in excess of 1.3 psi/ft. 16:00 20:00 4.00 703 DRIL Cored 3.032"hole f/620'1/703'with full returns. Flow line temp= 105 deg F. 20:00 21:00 1.00 600 SURV Surveyed @ 703'.4 deg. 21:00 0:00 3.00 793 DRIL Cored 3.032 hole f/703't/793'with full returns. Flow line temp= 105 deg F. Comments Nippled up BOP and tested. M/U NQ core tools and RIH. Cleaned out cement and cored new hole to 620'. Performed LOT-halted test at 596 psi surface pressure/1.3 psi gradient. Cored ahead t/793'. Casing/Tubular Information Type Size Top MD Top TVD Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.625 5 5 38 38 COND 10.000 FULL 4.500 5 5 186 186 SURF 5.500 832.00 FULL 3.500 5 5 596 596 INTI 3.780 1012.00 Mud Information % Gels Temp Mud Density Vis PV YP Filt. Cake pH/ES Solids Oil Water Sand LGS Chlor. Cal. 10s 10m 30m In Out Loss 19-Aug-10 20:00 Sample from Mud Pits 8.40 37 8 0 75 105 Bit/BHA/Workstring Information Depth This Run R.O.P. Mud Pump No Run Make Model Diam In Dist Hrs Avg Max WOB RPM Torque Wt Flow Press J.Vel P.Drp HHP JIF 6 1 ADT NQRS8 3.032 600 193 8.5 22.7 25.0 1200 8 35 210 Jets: Out: 1500 Grade: Cutter: / Dull / Wear: Brgs: Gge: Pull: Drilling Parameters Depth(ft) ROP(ft/hr) WOB(lbs) RPM Torque(ft lbs) Flow(gals/min) Pressure From To Avg Max Avg Max Avg Max Avg Max Avg Max (psi) 600 793 15.0 25.0 1100 1200 35 35 210 Annular Velocity: Drill Collars: 314.0 Drill Pipe: 314.0 Comments: Core 3.032 hole f/600'to 793',Flow line temp 105',dev survey's came back f/4 deg to 1/2 deg in 200' Printed: 09:17 14-Feb-14 RIMBase 7.0.2.114 Page: 1 of 2 Daily Drilling Report Geothermal Resource Group ii$ Well ID: AGP TG-4 Well Name: Hot Spring Bay Valley 4-Akutan Field: Hot Springs Bay W County:Aleutians East State:AK Country: United States Report No: 11 Report For 19-Aug-10 Survey Information Survey Meas. Vertical Coordinates Type Depth Inc. Azimuth TVD Closure Section N-S E-W D.L.S. TOTCO 703.0 4.00 TOTCO 803.0 2.50 TOTCO 903.0 0.50 Rig Information Equipment Problems: None.The inventory is what is on the rig only. Location Condition: Wet,muddy. Transport: Inventory Bulk Used This Received This Bulk Used This Received This Material Report Period Report Period Inventory Material Report Period Report Period Inventory DEFOAM14 5 DESCO CF 4.5 ZINC 1 CAUSTIC 5.75 BARITE 44 GEL 10 CaC 42 AQUA PAC 19 CEMENT 5 POLY VIS 1 0 TORKEASE 1 3.5 EZ-MUD 1 13 SODA ASH 98 Safety Information Meetings/Drills Time Description Safety 30 Crews held pre-tour safety meeting.LELS in cellar are checked twice every day. First Aid: Medical: Lost Time Accidents: Days Since LTA: 10 0 BOP Test ❑ Crownamatic Check Weather Information Sky Condition: Cloudy/Rain Visibility: Air Temperature: 46.0 degF Bar.Pressure: Wind Speed/Dir: / Wind Gusts: Printed: 09:17 14-Feb-14 RIMBase 7.0.2.114 Page:2 of 2 -._ ,, Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-4 Well Name: Hot Spring Bay Valley 4-Akutan Field: Hot Springs Bay Ve County:Aleutians East State:AK Country:United States Report No: 12 Report For 20-Aug-10 Operator: City Of Akutan Rig: Major LF90 Spud Date: 11-Aug-10 Daily Cost/Mud($): --- Measured Depth(ft): 1243 Drilling Days(act.): 10 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 1243 Drilling Days(plan): 24 RKB Elevation(ft): 5.00 --- --- --- Proposed TD(ft): 1500 Days On Location: 12 Last BOP Test: 19-Aug-10 --- --- --- Hole Made(ft)/Hrs: 450/20.0 Last Casing: 3.500 at 596 Shoe Test(lbs/gal): 1,012.00 Totals --- --- Average ROP(ft/hr): 22.5 Next Casing: 1.660 at 1,500 Working Interest: Well Cost($): --- Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 5 Total: 19 Current Operations: Cored 3.032"hole f/1243't/1373'with full returns.Flow line temp=105 deg. BHT=323 deg.F. Planned Operations: Finish coring well to 1500 ft.Run Pressure/Temperature surveys. Toolpusher: Dave Griggs Wellsite Supervisors: Randy Baldwin Tel No.: 1-907-444-1777 Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 0:30 0.50 803 DRIL Cored 3.032"hole f/793't1803'with full returns.Flow line temp=105 deg F. 0:30 1:30 1.00 803 SURV Surveyed @ 803'.2.25 deg. 1:30 4:30 3.00 903 DRIL Cored 3.032"hole f/803't/903'with full returns.Flow line temp=105 deg F. 4:30 5:30 1.00 903 SURV Surveyed @ 903'. .5 deg. 5:30 6:00 0.50 903 CIRC Condition hole. 6:00 11:00 5.00 1,001 DRIL Cored 3.032"hole f/903'U1001'with full returns.Flow line temp= 105 deg 11:00 11:30 0.50 1,001 SURV Surveyed @ 1001 ft. 4.00 deg. BHT=287 deg.F. 11:30 15:00 3.50 1,103 DRIL Cored 3.032"hole f/1001'U1103'with full returns.Flow line temp=105 deg 15:00 15:30 0.50 1,103 SURV Surveyed @ 1103 ft. 2.25 deg. BHT=279 deg. F. 15:30 21:30 6.00 1,203 DRIL Cored 3.032"hole f/1103'U1203'with full returns.Flow line temp=105 deg 21:30 22:00 0.50 1,203 SURV Surveyed @ 1203 ft, 1.25 deg. BHT=305 deg F. 22:00 0:00 2.00 1,243 DRIL Cored 3.032"hole f/1203't/1243'with full returns.Flow line temp=105 deg Comments Cored 3.032"hole f/793'U1243'with full returns.Survey every 100 ft. Flow line temp=105 deg BHT=305 deg.F. Casing/Tubular Information Type Size Top MD Top TVD Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.625 5 5 38 38 COND 10.000 FULL 4.500 5 5 186 186 SURF 5.500 832.00 FULL 3.500 5 5 596 596 INTI 3.780 1012.00 Mud Information % Gels Temp Mud Density Vis PV YP Fitt. Cake pH/ES Solids Oil Water Sand LGS Chlor. Cal. 10s 10m 30m In Out Loss 20-Aug-10 20:00 at Depth 1,203 ft Sample from Mud Pits 8.40 37 8 0 80 105 Bit/BHA/Workstring Information Depth This Run R.O.P. Mud Pump No Run Make Model Diam In Dist Hrs Avg Max WOB RPM Torque Wt Flow Press J.Vel P.Drp HHP JIF 6 1 ADT NQRS8 3.032 600 643 28.5 22.6 25.0 1200 8 35 250 Jets: Out: 1500 Grade: Cutter: / Dull / Wear: Brgs: Gge: Pull: Drilling Parameters Depth(ft) ROP(ft/hr) WOB(lbs) RPM Torque(ft lbs) Flow(gals/min) Pressure From To Avg Max Avg Max Avg Max Avg Max Avg Max (psi) 793 1,293 22.0 25.0 1100 1200 35 35 250 Annular Velocity: Drill Collars: 314.0 Drill Pipe: 314.0 Comments: Cored 3.032"hole f/793'U1243'with full returns.Survey every 100 ft. Flow line temp=105 deg BHT=305 deg.F. Printed: 09:17 14-Feb-14 R/MBase 7.0.2.114 Page: 1 of 2 Daily Drilling Report Geothermal Resource Group RG Well ID: AGP TG-4 Well Name: Hot Spring Bay Valley 4-Akutan Field: Hot Springs Bay Ve County:Aleutians East State:AK Country: United States Report No: 12 Report For 20-Aug-10 Survey Information Survey Meas. Vertical Coordinates Type Depth Inc. Azimuth TVD Closure Section N-S E-W D.L.S. TOTCO 1,001.0 4.00 TOTCO 1,103.0 2.25 TOTCO 1,203.0 1.25 Rig Information Equipment Problems: None.The inventory is what is on the rig only. Location Condition: Wet,muddy. Transport: Solids Control Information Inventory Bulk Used This Received This Bulk Used This Received This Material Report Period Report Period Inventory Material Report Period Report Period Inventory POLY VIS 0 TORKEASE 3.5 20 20 EZ-MUD 12 1 SODA ASH 98 DEFOAM14 5 DESCO CF 4.5 ZINC 1 CAUSTIC 5.75 BARITE 44 GEL 10 CaC 42 AQUA PAC 19 CEMENT 5 Safety Information Meetings/Drills Time Description Safety 30 Crews held pre-tour safety meeting. LELS in cellar are checked twice every day. First Aid: Medical: Lost Time Accidents: Days Since LTA: 11 ❑ BOP Test ❑ Crownamatic Check Weather Information Sky Condition: Cloudy Visibility: Air Temperature: 55.0 degF Bar.Pressure: Wind Speed/Dir: 0/ Wind Gusts: Printed: 09:17 14-Feb-14 R/MBase 7.0.2.114 Page:2 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TGA Well Name: Hot Spring Bay Valley 4-Akutan Field: Hot Springs Bay V8 County:Aleutians East State:AK Country: United States Report No: 13 Report For 21-Aug-10 Operator: City Of Akutan Rig: Major LF90 Spud Date: 11-Aug-10 Daily Cost/Mud($): --- Measured Depth(ft): 1500 Drilling Days(act.): 11 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 1500 Drilling Days(plan): 24 RKB Elevation(ft): 5.00 --- --- --- Proposed TD(ft): 1500 Days On Location: 13 Last BOP Test: 19-Aug-10 --- --- --- Hole Made(ft)/Hrs: 257/13.0 Last Casing: 3.500 at 596 Shoe Test(lbs/gal): 1,012.00 Totals --- --- Average ROP(ft/hr): 19.77 Next Casing: 1.660 at 1,500 Working Interest: Well Cost($): --- Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 5 Total: 19 Current Operations: Waited for well to heat up.Started running 1st Pressure/Temperature log @ 04:30 hrs. Planned Operations: Run Pressure/Temperature logs. Toolpusher: Dave Griggs Wellsite Supervisors: Randy Baldwin Tel No.: 1-907-444-1777 _ Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 4:00 4.00 1,303 DRIL Cored 3.032"hole f/1243't11303'with full returns. Flow line temp= 105 deg 4:00 4:30 0.50 1,303 SURV Surveyed at 1303 ft. 1 deg. BHT=323 deg F. 4:30 8:00 3.50 1,403 DRIL Cored 3.032"hole f/1303't11403'with full returns. Flow line temp= 105 deg 8:00 8:30 0.50 1,403 SURV Surveyed at 1403 ft. 0.5 deg. BHT=330 deg F. 8:30 14:00 5.50 1,500 DRIL Cored 3.032"hole f/1403'U1500'with full returns. Flow line temp=105 deg 14:00 14:30 0.50 1,500 SURV Surveyed at 1500 ft. 2 deg. BHT=323 deg. F. 14:30 16:00 1.50 1,500 CIRC Circulate and clean hole. 16:00 16:30 0.50 1,500 COOL Mix and pump 9.5 ppg CaCl2 water. 16:30 0:00 7.50 1,500 TEST Waiting on well to heat up for 12 hrs prior to pressure and temperature logging. Comments Cored 3.032"hole f/1243'U1500'with full returns.Flow line temp=105 deg. BHT=323 deg F. Circulate hole clean,Change hole over to 9.5 CaCl2 water.Waiting on well to heat up for 12 hrs prior to pressure and temperature logging. Casing/Tubular Information Type Size Top MD Top TVD Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.625 5 5 38 38 COND 10.000 FULL 4.500 5 5 186 186 SURF 5.500 832.00 FULL 3.500 5 5 596 596 INTI 3.780 1012.00 Mud Information % Gels Temp Mud Density Vis PV YP Filt. Cake pH/ES Solids Oil Water Sand LGS Chlor. Cal. 10s 10m 30m In Out Loss 21-Aug-10 15:00 at Depth 1,500 ft Sample from Mud Pits 8.50 37 8 90 105 Bit/BHA/Workstring Information Depth This Run R.O.P. Mud Pump No Run Make Model Diam In Dist Hrs Avg Max WOB RPM Torque Wt Flow Press J.Vel P.Drp HHP JIF 6 1 ADT NQRS8 3.032 600 900 41.5 21.7 1100 8 35 250 Jets: Out: 1500 Grade: Cutter: / Dull / Wear: Brgs: Gge: Pull: Drilling Parameters Depth(ft) ROP(ft/hr) WOB(lbs) RPM Torque(ft lbs) Flow(gals/min) Pressure From To Avg Max Avg Max Avg Max Avg Max Avg Max (psi) 1,243 1,500 21.0 25.0 1100 1200 35 35 250 Annular Velocity: Drill Collars: 314.0 Drill Pipe: 314.0 Comments: Cored 3.032"hole f/793'U1243'with full returns.Survey every 100 ft. Flow line temp=105 deg BHT=305 deg.F. Printed: 09:17 14-Feb-14 RIMBase 7.0.2.114 Page: 1 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-4 Well Name: Hot Spring Bay Valley 4-Akutan Field: Hot Springs Bay Va County:Aleutians East State:AK Country: United States Report No: 13 Report For 21-Aug-10 Survey Information Survey Meas. Vertical Coordinates Type Depth Inc. Azimuth TVD Closure Section N-S E-W D.L.S. TOTCO 1,303.0 1.00 TOTCO 1,403.0 0.50 TOTCO 1,500.0 2.00 Rig Information Equipment Problems: None.The inventory is what is on the rig only. Location Condition: Wet,muddy. Transport: Inventory Bulk Used This Received This Bulk Used This Received This Material Report Period Report Period Inventory Material Report Period Report Period Inventory POLY VIS 0 TORKEASE 10 10 EZ-MUD 1 0 SODA ASH 98 DEFOAM14 5 DESCO CF 4.5 ZINC 1 CAUSTIC 5.75 BARITE 44 GEL 10 CaC 42 AQUA PAC 19 CEMENT 5 Safety Information Meetings/Drills Time Description Safety 30 Crews held pre-tour safety meeting.LELS in cellar are checked twice every day. First Aid: Medical: Lost Time Accidents: Days Since LTA: 12 ❑ BOP Test ❑ Crownamatic Check Weather Information Sky Condition: Cloudy Visibility: 3 Air Temperature: 53.0 degF Bar.Pressure: Wind Speed/Dir: 10/NE Wind Gusts: 15 Printed: 09:17 14-Feb-14 RIMBase 7.0.2.114 Page:2 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TGA Well Name: Hot Spring Bay Valley 4-Akutan Field: Hot Springs Bay Va County:Aleutians East State:AK Country: United States Report No: 14 Report For 22-Aug-10 Operator: City Of Akutan Rig: Major LF90 Spud Date: 11-Aug-10 Daily Cost/Mud($): --- Measured Depth(ft): 1500 Drilling Days(act.): 12 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 1500 Drilling Days(plan): 24 RKB Elevation(ft): 5.00 --- --- --- Proposed TD(ft): 1500 Days On Location: 14 Last BOP Test: 19-Aug-10 --- --- --- Hole Made(ft)/Hrs: 0/0.0 Last Casing: 3.500 at 596 Shoe Test(lbs/gal): 1,012.00 Totals --- --- Average ROP(ft/hr): Next Casing: 1.660 at 1,500 Working Interest: Well Cost($): --- Personnel: Operator: 3 Contractor: 7 Service: 5 Other: 4 Total: 19 Current Operations: Running 36 hour Pressure/Temperature log. Planned Operations: Finish PT logs, change hole over to water, POOH. Unload well. Toolpusher: Dave Griggs Wellsite Supervisors: Randy Baldwin Tel No.: 1-907-444-1777 Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 4:30 4.50 1,500 TEST Allow well to heat up for 12 hour Pressure/Temperature logs. 4:30 11:30 7.00 1,500 TEST Opened well&began 12 hour Pressure/Temperature logs. Initial stop at 50'and 100', followed by 20'stops to TD. 11:30 16:30 5.00 1,500 TEST Allow well to heat up for 24 hour Pressure/Temperature logs. 16:30 23:30 7.00 1,500 TEST Opened well&began 24 hour Pressure/Temperature logs. Initial stop at 50'and 100', followed by 20'stops to TD. 23:30 0:00 0.50 1,500 TEST Allow well to heat up for 36 hour Pressure/Temperature logs. Comments Run 12 and 24 hour Pressure/Temperature logs. Casing/Tubular Information Type Size Top MD Top TVD Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.625 5 5 38 38 COND 10.000 FULL 4.500 5 5 186 186 SURF 5.500 832.00 FULL 3.500 5 5 596 596 INTI 3.780 1012.00 Mud Information Gels Temp Mud Density Vis PV YP Filt. Cake pH/ES Solids Oil Water Sand LGS Chlor. Cal. 10s 10m 30m In Out Loss 22-Aug-10 17:00 at Depth 1,500 ft Sample from Mud Pits,Type:Water 8.33 28 6.5 0 Bit/BHA/Workstring Information Depth This Run R.O.P. Mud Pump No Run Make Model Diam In Dist Hrs Avg Max WOB RPM Torque Wt Flow Press J.Vel P.Drp HHP JIF 6 1 ADT NQRS8 3.032 600 900 41.5 0.0 0.0 0 0 0 8 0 0 Jets: Out: 1500 Grade: Cutter: / Dull / Wear: Brgs: Gge: Pull: Rig Information Equipment Problems: None.The inventory is what is on the rig only. Location Condition: Wet, muddy. Transport: Inventory Bulk Used This Received This Bulk Used This Received This Material Report Period Report Period Inventory Material Report Period Report Period Inventory ZINC 1 CAUSTIC 5.75 BARITE 44 I GEL 10 CaC 42 AQUA PAC 19 CEMENT 5 POLY VIS 0 TORKEASE 10 EZ-MUD 0 SODA ASH 98 I DEFOAM14 5 DESCO CF 4.5 Printed: 09:17 14-Feb-14 RIMBase 7.0.2.114 Page: 1 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-4 Well Name: Hot Spring Bay Valley 4-Akutan Field: Hot Springs Bay Va County:Aleutians East State:AK Country: United States Report No: 14 Report For 22-Aug-10 Safety Information Meetings/Drills Time Description Safety 30 Crews held pre-tour safety meeting.LELS in cellar are checked twice every day. First Aid: Medical: Lost Time Accidents: Days Since LTA: 13 0 BOP Test Crownamatic Check Weather Information Sky Condition: Partly cloudy Visibility: 5 Air Temperature: 55.0 degF Bar.Pressure: Wind Speed/Dir: 5/E Wind Gusts: 15 Printed: 09:17 14-Feb-14 RIMBase 7.0.2.114 Page:2 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-4 Well Name:Hot Spring Bay Valley 4-Akutan Field: Hot Springs Bay Ve County:Aleutians East State:AK Country: United States Report No: 15 Report For 23-Aug-10 Operator: City Of Akutan Rig: Major LF90 Spud Date: 11-Aug-10 Daily Cost/Mud($): --- Measured Depth(ft): 1500 Drilling Days(act.): 13 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 1500 Drilling Days(plan): 24 RKB Elevation(ft): 5.00 --- --- --- Proposed TD(ft): 1500 Days On Location: 15 Last BOP Test: 19-Aug-10 --- --- --- Hole Made(ft)/Hrs: 0/0.0 Last Casing: 3.500 at 596 Shoe Test(lbs/gal): 1,012.00 Totals --- --- Average ROP(ft/hr): Next Casing: 1.660 at 1,500 Working Interest: Well Cost($): --- Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 5 Total: 19 Current Operations: Stage in hole,unloading with air to 1100 ft. Planned Operations: Perform injection test. Run 1 1/4 inch tubing. Toolpusher: Dave Griggs Wellsite Supervisors: Randy Baldwin Tel No.: 1-907-444-1777 Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 4:30 4.50 1,500 TEST Allow well to heat up for 36 hour Pressure/Temperature logs. 4:30 11:30 7.00 1,500 TEST Opened well&began 36 hour Pressure/Temperature logs. Initial stop at 50'and 100', followed by 20'stops to TD. 11:30 12:00 0.50 1,500 CIRC Circulate hole over to fresh water. 12:00 13:30 1.50 1,500 TRPO POOH with bit and NQ rod. 13:30 0:00 10.50 1,500 TEST Close master valve,allow well to heat up. Comments Run 36 hour Pressure/Temperature log.Change hole over to water.POOH. Close master valve,allow well to heat up. Casing/Tubular Information Type Size Top MD Top ND Bottom MD Bottom ND Hole Section Avg OH Diam LOT FULL 6.625 5 5 38 38 COND 10.000 FULL 4.500 5 5 186 186 SURF 5.500 832.00 FULL 3.500 5 5 596 596 INTI 3.780 1012.00 Mud Information % Gels Temp Mud Density Vis PV YP Filt. Cake pH/ES Solids Oil Water Sand LGS Chlor. Cal. 10s 10m 30m In Out Loss 23-Aug-10 17:00 at Depth 1,500 ft Sample from Mud Pits,Type:Water 8.33 27 7 100 _ _ Bit/BHA/Workstring Information Depth This Run R.O.P. Mud Pump No Run Make Model Diam In Dist Hrs Avg Max WOB RPM Torque Wt Flow Press J.Vel P.Drp HHP JIF 6 1 ADT NQRS8 3.032 600 900 41.5 0.0 0.0 0 0 0 8 35 200 Jets: Out: 1500 Grade: Cutter: / Dull / Wear: Brgs: Gge: Pull: Rig Information Equipment Problems: None.The inventory is what is on the rig only. Location Condition: Wet,muddy. Transport: Inventory Bulk Used This Received This Bulk Used This Received This Material Report Period Report Period Inventory Material Report Period Report Period Inventory ZINC 1 CAUSTIC 5.75 BARITE 44 GEL 10 CaC 42 AQUA PAC 19 CEMENT 5 POLY VIS 0 TORKEASE 10 EZ-MUD 0 SODA ASH 98 DEFOAM14 5 DESCO CF 4.5 Printed: 09:17 14-Feb-14 R/MBase 7.0.2.114 Page: 1 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-4 Well Name: Hot Spring Bay Valley 4-Akutan Field: Hot Springs Bay Vo County:Aleutians East State:AK Country: United States Report No: 15 Report For 23-Aug-I 0 Safety Information Meetings/Drills Time Description Safety 30 Crews held pre-tour safety meeting. LELS in cellar are checked twice every day. First Aid: Medical: Lost Time Accidents: Days Since LTA: 14 ❑ BOP Test ❑ Crownamatic Check Weather Information Sky Condition: Partly coludy Visibility: 10 Air Temperature: 55.0 degF Bar.Pressure: Wind Speed/Dir: 10/SW Wind Gusts: 15 Printed: 09:17 14-Feb-14 RIMBase 7.0.2.114 Page:2 of 2 Daily Drilling Report Geothermal Resource Group Well ID:AGP TG-4 Well Name: Hot Spring Bay Valley 4-Akutan Field: Hot Springs Bay Va County:Aleutians East State:AK Country: United States Report No: 16 Report For 24-Aug-10 Operator: City Of Akutan Rig: Major LF90 Spud Date: 11-Aug-10 Daily Cost/Mud($): --- Measured Depth(ft): 1500 Drilling Days(act.): 14 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 1500 Drilling Days(plan): 24 RKB Elevation(ft): 5.00 --- --- --- Proposed TD(ft): 1500 Days On Location: 16 Last BOP Test: 19-Aug-10 --- --- --- Hole Made(ft)/Hrs: 0/0.0 Last Casing: 1.660 at 1,491 Totals --- --- Average ROP(ft/hr): Next Casing: Working Interest: Well Cost($): --- Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 5 Total: 19 Current Operations: Waiting on daylight. FINAL REPORT. Planned Operations: Continue demob of rig. Toolpusher: Dave Griggs Wellsite Supervisors: Randy Baldwin Tel No.: 1-907-444-1777 Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 6:00 6.00 1,500 UNLOAD Stage in hole to 1100 ft. in 100/ft increments,unloading well with air.Getting approx 4 to 5 gals/min.of water back after intial blow down. 6:00 8:00 2.00 1,500 UNLOAD Unload well with air at 1100 ft.Let blow for 1 hour.Shut air off,well quit flowing. 8:00 9:00 1.00 1,500 TRPO Pull up to shoe. 9:00 12:00 3.00 1,500 EVAL Perform injection test at 1 gal/min,2 gal/min,and 2.5 gal/min. 12:00 13:00 1.00 1,500 TRPO POOH. 13:00 16:00 3.00 1,500 TRPI RIH with 1 1/4 inch tubing t/1491 ft.with check valve on bottom. 16:00 17:30 1.50 1,500 BOPND Nipple down BOPs. 17:30 18:00 0.50 1,500 BOPO Install wellhead. Secure well. Release rig. 18:00 20:00 2.00 1,500 MOB Demob rig,lay mast over. 20:00 0:00 4.00 1,500 OTHER Waiting on daylight. Comments Unload well to 1100 ft.with air.Perform injection test. RIH with 1 1/4 inch tubing to 1491 ft. Nipple down BOPs,Install wellhead.Secure well,and demob rig. Casing/Tubular Information Type Size Top MD Top TVD Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.625 5 5 38 38 COND 10.000 FULL 4.500 5 5 186 186 SURF 5.500 832.00 FULL 3.500 5 5 596 596 INTI 3.780 1012.00 HNG DN 1.660 0 0 1491 1491 2.980 Rig Information Equipment Problems: None.The inventory is what is on the rig only. Location Condition: Wet,muddy. Transport: Inventory Bulk Used This Received This Bulk Used This Received This Material Report Period Report Period Inventory Material Report Period Report Period Inventory DESCO CF 4.5 ZINC 1 CAUSTIC 5.75 BARITE 44 GEL 10 CaC 42 AQUA PAC 19 CEMENT 5 POLY VIS 0 TORKEASE 10 EZ-MUD 0 SODA ASH 98 DEFOAM14 5 Safety Information Meetings/Drills Time Description Safety 30 Crews held pre-tour safety meeting.LELS in cellar are checked twice every day. First Aid: Medical: Lost Time Accidents: Days Since LTA: 15 ❑ BOP Test ❑ Crownamatic Check Printed: 09:17 14-Feb-14 RIMBase 7.0.2.114 Page: 1 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-4 Well Name: Hot Spring Bay Valley 4-Akutan Field: Hot Springs Bay W County: Aleutians East State:AK Country: United States Report No: 16 Report For 24-Aug-10 Weather Information Sky Condition: Cloudy,light rain. Visibility: 10 Air Temperature: 53.0 degF Bar.Pressure: Wind Speed/Dir: 15/NE Wind Gusts: 25 l Printed: 09:17 14-Feb-14 RIMBase 7.0.2.114 Page:2 of 2 f E"CLo ?-7-L) -0-73 FEB 192014 AKUTAN A000C UNIMAK ISLAND AKUTAN ' UNALASKA ISLAND • UMNAKISLAND 5�r To: Guy Schwartz,Alaska Oil and Gas Conservation Commission From: Mary Tesche, Assistant City Administrator Date: February 19, 2014 Re: Akutan Geothermal Project Core Samples and Additional Information Mr. Schwartz: At the request of AOGCC, the City of Akutan is providing materials and information for the Akutan Hot Springs Well 2 and South Elbow Well 4, both part of the Akutan Geothermal Project. Below is an inventory list of the provided information: • Five(5) HSB-4 sample containers, labeled from 0' to 1500' • One(1) HSB-4 sample container,no label • Nine (9) HSB-2 sample containers, labeled from 0' to 830' • Binder - Supplementary Materials for Akutan Hot Spring Well 2 and South Elbow Well 4, with CD • Akutan Core Data DVD Please let me know if you need any additional information or have any questions. Cordially, Mary Tesche Assistant City Administrator City of Akutan 907.777.1643 Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Tuesday, January 14, 2014 11:40 AM To: 'akutanadmin@gci.net' Cc: Schwartz, Guy L (DOA) Subject: Hot Springs Well 2 and South Elbow Well 4: Missing Information Mr. Scanlan: The following items that have not been submitted to the Alaska Oil and Gas Conservation Commission (AOGCC)for the Hot Springs Well No. 2 and South Elbow No.4 exploratory geothermal wells. These items are required by Regulations 20 AAC 25.070 and 20 AAC 25.071. 1. Conventional cores: a. core photographs; b. analytical results from porosity, permeability, mineralogy or petrographic studies conducted by Western Washington University or by commercial laboratories; and c. chip samples from conventional cores as described in regulation 20 AAC 25.071. 2. Flow tests: pressure, temperature and flow charts and data (both qualitative and quantitative) recorded during every flow test. 3. Fluid samples: geochemical analyses conducted by Western Washington University or by commercial laboratories. Please contact me if you have any questions. Regards, Steve Davies Sr. Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 Fax: 907-276-7542 1 RECEIVED STATE OF ALASKA OCT 14 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND SCC la.Well Status: Oil❑ Gas ❑ SPLUG❑ Other ❑ Abandoned 0. Suspended❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory 0 GINJ ❑ WINJ❑ WAG❑ WDSPL❑ No.of Completions: _1 Service ❑ Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp.,or 12.Permit to Drill Number: City of Akutan Aband, 9/15/2013 210073 , 3.Address: 6.Date Spudded: 13.API Number: 3380 C Street,Suite 205,Anchorage,AK 99503-3952 8/11/2010 • 50-295-20004-00-00 ' 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 5135'S, 1695'E,S7,T70S,R112W.SM 8/21/2010 - South Elbow Well/4 • Top of Productive Horizon: 8.KB(ft above MSL): 123 15.Field/Pool(s): 5135'S, 1695'E,S7,170S,R112W.SM GL(ft above MSL): 119 Hot Springs Bay Valley Total Depth: 9.Plug Back Depth(MD+TVD): 5135'5, 1695'E,S7,170S,R112W.SM N/A 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x- 526623.5 y- 50556.3 Zone- 8 1500'+1500' Fee Agent Corporation TPI: x- 526623.5 y- 50556.3 Zone- 8 11.SSSV Depth(MD+TVD): 17. Land Use Permit: Total Depth: x- 526623.5 y- 50556.3 Zone- 8 N/A Subsurface Agreements 18.Directional Survey: Yes ❑ No 0 Drift surveys while drilling 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) (ft MSL) N/A 21.Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drill/Lateral Top Window MD/TVD: N/A 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 6.625 20 K55 0 33 0 33 9.875 Tremie w/13.5#Type 2 Premiu 0 4.5 11.2 4130 3 186 3 186 5.5 13.5#Type 2 Premium w/30% 0 3.5 8.69 4130 3 596 3 596 3.87 13.5#Type 2 Premium w/30% 0 24.Open to production or injection? Yes❑ No0 If Yes,list each 25. TUBING RECORD Foot valve at end of 1.66"tubing-tubing can only be circulated from surface. SIZE DEPTH SET(MD) PACKER SET(MDITVD) / 1.66 1491 0(hung from wellhead) ✓le 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. , DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED " :c1. 27. PRODUCTION TEST Date First Production: N/A Method of Operation(Flowing,gas lift,etc.): Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period -0 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate -0 28. CORE DATA Conventional Core(s)Acquired? Yes 0 • No❑ Sidewall Cores Acquired? Yes❑ No 0 . If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize Iithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. 7/(e/ /Z-If' l3 R8 1S OCT 15 2013 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? El Yes ❑ No If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if needed, Permafrost-Top and submit detailed test information per 20 AAC 25.071. Permafrost-Base Performed formation integrity test to 0.625 gradient at 173'.Performed test to Alluvium full leakoff at 623',leakoff obtained at 0.52 gradient. Squeezed cement and Akutan tested again,leakoff obtained at 0.74 gradient. Well allowed to flow after completion of drilling and formation fluid samples were obtained. Formation at total depth: 31. List of Attachments: Mud logs and pressure/temperature logs. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: G.1C,trt.%a►1 Q4 rh!Diet•wit Printed Name: RttZliti./cW4.{-pi 1 Title: p kM 1h)I5The 'rpa-- Signature: .L( Phone: ' 17^ a74'7 X^ Date: (-O t 4(210�� INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item lb: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. 0 Geothermal Resource Group TAPPING THE EARTH'S ENERGY South Elbow Well/TG-4 • On September 9th 2013,team initially moved equipment to site during the 2"d half of the day. • September 10th, we finished moving equipment and began to rig up TG-4 site—soon after that, operations had to shut down because of bad weather. • September 11th, arrived at the rig site, rigged up to relieve pressure from the wellhead,and was able to circulate water through the tubing and out the annulus through 1" and%"valves on the annulus. 1, 4 a• + ti -0,440---/ `` ,. Y ! , iyir ar 0:800:4?0,„4- - _ -. .... .,,„, , , s A: `� rr . ..SSS SS Figure 1-Rigged up on TG-4 wellhead to circulate water prior to cementing. • September 12th, pumped and circulated about 800 gal of water prior to pumping 37cu. ft. of 13.3 ppg TC-Geolite class B premium cement. At 37 cu. ft.the pump was no longer able to pump cement due to an obstruction in the tubing. Broke off of tubing and shut in the 1.66" valve. Rigged up to go through the 1"to initially attempt a squeeze with water—only was able to pump 8 gallons of water(>1.2 psi/ft. measured gradient of well). Relieved pressure in annulus through 1/2"valve while leaving the 1"rigged up. Representative of the AEA arrived on site to do in-person inspection of operations. Shut down site due to bad weather coming into the valley. Geolhermal Resource Group TAPPING THE EARTH'S ENERGY • September 13h,there was bad weather in the morning postponing operations until the afternoon. Received verbal approval from AOGCC to perform tremie job on well. Went to TG-4 and ran copper tremie pipe to 49' from surface. ii fel . ; rA t - k a ` a. Al*i * ry4 Figure 2-Tremie pipe through annulus opening down to 49'below grade,note that cement is in tubing to surface. • September 14th, waited on cement throughout morning and mid-day, and at the end of the day mobilized completion equipment from TG-2 to TG-4 site. • September 15th, performed annulus top job by pumping 4 cu. ft. of 13.3 ppg TC-Geolite class B premium cement,with no retardant,through tremmie until there were acceptable returns at surface. Waited a minimum of 8 hours to return and complete welding operations. After 8.5 hours of waiting on cement,the wellhead was cut off 3 ft. below grade. Tubing was in place at surface (suspended in hard cement). Welded plate over structural casing and tubing,welded on name plate. • September 15th, cellar culvert was removed and cellar was filled. Geothermal Resource Group TAPPING THE EARTH'S ENERGY � g,,w' Via. i • a c 0 f' .p: .., .: ,, Figure 3-Cutting off the wellhead as close to the cellar floor as possible. :-•t r . . lo .. :,-"or: i,.4.'1:-. , ' r "� t " ic..; ' : .. ". T a 4 " ' iEr ,: _ ,_ _ I. "�� � , h. Figure 4-After cutting off wellhead,notice that tremie pipe and tubing are cemented in place. • Geothermal Resource Group TAPPING THE EARTH'S ENERGY ---i- 1 ..675"OD casing- ,.5"OD casing- 3.5"OD casing- 1.66"OD casing- Figure 5-Note that the 3.5"casing is below the level of the 4.5''casing,due to being set with a landing joint. r ;;x +ivµ d µ r Figure 6-A 4"plate is welded on over the structural casing,and is below grade by at least 38". ' * Geothermal Resource Group TAPPING THE EARTH'S ENERGY P c ''''i u, - • ) ; 4,, 1r if I j , , " F 'i , r';f .. a 4 , t ,I '{ (a e°: S ,� • 4 ', :' ;''..?',-;.• :1;!'„,7,,,,..,•k, L,, . _ xyi I .'..v .,..:, .. Figure 7-Nameplate(6")to be welded on with Permit number. $"i 4 Ai • • .. � s Figure 8-South Elbow Well/TG-4 plugged,abandoned and with welded plates. Geothermal Resource Group 1)0 TAPPING THE EARTH'S ENERGY 4,,c .. 4 '.Yigr'i�,.""r," t:i�..a^ 3M4 '1 0C Jd 1*.:3 My X Figure 9—TG-4 well site after operations were completed and was filled in back to grade level. Akutan TG-4 MK AM "South Elbow"Well 4' / 6-5/8" Conductor at 37' Fully Cemented ��\ 24p- 075 � ild-C 13.S pi, 71.3 \ -IN 7161y) 4 %" 0.25 WT Casing at 186' CW 1 ` Fully Cemented 7 Pt-3 /3.3 /vea_ 3-%2" 0.25WT Casing at 596' I c 0 m r 3.01" Open Hole to 1500' — 1.660" 2.4ppf Tubing, Hung from Surface to 1491' • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Monday, September 16,2013 10:36 AM To: Alan Bailey Cc: Jonathan Hernandez; Bill Rickard Subject: RE: Use of tremie to abandon TG-4 Alan, Thanks for the email... Trust you got TG-4 buttoned up before weather hit. Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office From: Alan Bailey [mailto_alanbailey a geothermalresourcegroup.c om] Sent: Monday, September 16, 2013 8:40 AM To: Schwartz, Guy L(DOA) Cc: Jonathan Hernandez; Bill Rickard Subject: Use of tremie to abandon TG-4 Good Morning Guy, As per your request,the following is a synopsis of the method used to abandon TG-4 on Akutan.An obstruction in the inner tubing left by a temperature logging team prevented us from abandoning the well through the tubing. It was necessary to run a tremie from the surface down in order to accomplish it.The tremie was 1/2" nominal copper tubing and we were able to reach a total of 44'with it.We pumped unretarded Premium I-II cement with 40%silica flour back to surface and allowed it to harden for 8 hours.Once the cement had built sufficient strength,we cut off more the wellhead and cut down so that the top of the cutoff would be greater than 36" below ground level.A 4"diameter plate was welded onto the the 4-1/2"foundation casing string,and a name plate was welded onto it.The cellar will be backfilled to surface today. Best regards, Alan Bailey Manager of Engineering Geothermal Resource Group,Inc. .11,11;1-,111c\ :.tic0lhrrnt;tlrr0.)111 760-341-0186 Office 760-341-9673 Fax 775-304-3253 Cell htln;_ cothc_rnm:111c.0urcc2 ruul;.Lon, The contents of this email message and any attachments are confidential and are intended solely for addressee.The information may also be legally privileged.This transmission is sent in trust,for the sole purpose of delivery to the intended recipient.If you have received this transmission in error,any use,reproduction or dissemination of this transmission is strictly prohibited.If you are not the intended recipient,please immediately notify the sender by reply and delete this message and its attachments,if any. 1 Schwartz, Guy L (DOA) From: Schwartz,Guy L(DOA) Sent: Friday, September 13,2013 2:02 PM To: Alan Bailey Cc: Bill Rickard;Jonathan Hernandez Subject: RE:TG-4 Abandonment Issues(210-073) Alan, As per our phone call try to get small Dia. Pipe alongside the 1.66" before cutting and dropping tubing. Looks like the 1.66" tubing is hung off center slightly looking a pics of TG-2 wellhead. If that doesn't work call me back. We would like to get 100' or so of surface cement if possible. I talked to Commissioner Foerster and she agrees with setting a surface plug only due to the current situation and that the rock is super tight. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office From: Alan Bailey [mailto:alanbailey�a geotherrnalresourcegroup.com] Sent: Friday, September 13, 2013 12:05 PM To: Schwartz, Guy L(DOA) Cc: Bill Rickard; Jonathan Hernandez Subject: TG-4 Abandonment Issues Guy, I would like to discuss issues that we are having with the abandonment of well TG-4. TG-4 was drilled in August of 2010.There is a 6-5/8" conductor at 38', a 4.5" casing string with a fully cemented annulus set at 186 ft, a 3.5" casing string set at 596' with a fully cemented annulus, and a string of 1.66 inch tubing hung from surface to 1491'.The 4.5" casing was tested to a 12 ppg gradient with no leak off. A leak-off test was performed to a 1.3 psi/ft or 25 ppg with no leak off.The well has no entries,tests like casing, and shows no evidence that it will ever flow. Subsequent to the 2012 MT and gravity work, it has been / determined that the well is not located in the active resource,there are no nearby surface manifestations, and for all the evidence is completely isolated from potential reservoir activity. • During the summer of 2011, a group from the village went out to run temperature surveys on the wells. When running the temperature survey,they dropped a 324" diameter sinker bar into the 1-1/4" ID tubing, creating a partial obstruction at the bottom of the tubing. On Wednesday the 10th,we rigged up and broke circulation. 1 On Thursday the 11th, we were linea up with the TG-4 well to begin pumping cement. Initially,the crew pumped cold water to cool the well. After circulating the old mud from the annulus and cooling the well, cement was pumped, but upon reaching the sinker bar,the cement jugged up and they were unable to pump any longer. The tubing is now filled with cement from the bottom of the tubing to 600' and from 600' back to surface.The crew pressured up on the tubing sufficiently to achieve a 24.0 ppg equivalent weight (1200' of cement in hole @ 13.2 ppg and water spacer), and the cement was properly retarded. Subsequently,the pumping unit was lined up to try to bullhead down the annulus. The bull-heading attempt applied the full 800- psi force of the pump, reaching a 1.78 psi/ft/34-ppg equivalent mud weight at the shoe, and still we could not pump into the formation. A second attempt was attempt was made to bullhead cement from surface, but this too was unsuccessful.The annulus of the TG-4 well remains un-abandoned, and is impermeable. - At this time,we would like to ask that a variance be granted in the abandonment method to be employed. We would like to perform the following actions to abandon TG4. First,we would like to cut the tubing and allow it to drop into the well. Second we would like to use a tremie in order to fill at least the top 20 feet of the hole with cement. Third, we will cut off 3' below ground level, weld the casing closed, and install the nameplate to the well. Finally,we would like to backfill over the well with at least 2 feet of cement,then complete backfilling the cellar. Our alternative is to bring a rig out and pull the tubing. This will not occur for several years at least, until the • drilling campaign begins. Best regards, Alan Bailey Manager of Engineering Geothermal Resource Group,Inc. �lant�rricy c_s,co!hcrruEilresourcc;2,1 out)coax 760-341-0186 Office 760-341-9673 Fax 775-304-3253 Cell http jjgeothermalresourcegraup.c:orn The contents of this email message and any attachments are confidential and are intended solely for addressee.The information may also be legally privileged.This transmission is sent in trust,for the sole purpose of delivery to the intended recipient.If you have received this transmission in error,any use,reproduction or dissemination of this transmission is strictly prohibited.If you are not the intended recipient,please immediately notify the sender by reply and delete this message and its attachments,if any. 2 s. THE STATE Ansa Oil and Gas of LAs Conservation Commission == GOVERNOR SEAN PARNELL 333 West Seventh Avenue (4ALAS Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Herman J. Scanlan City Administrator City of Akutan 3 3380 C Street, Suite 205 gjto — 0 7 Anchorage, AK 99503 Re: Hot Springs Bay Valley, South Elbow Well-4 Sundry Number: 313-429 Dear Mr. Scanlan: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster Chair - - DATED this /2 day of August, 2013. Encl. RECEIVED STATE OF ALASKA ! I G 0 7 201 ALASKA OIL AND GAS CONSERVATION COMMISSION DTS 8112. 13 APPLICATION FOR SUNDRY APPROVALS A000 20 AAC 25.280 1.Type of Request: Abandon- Plug for Redrill ❑ Perforate New Pool D Repair Well❑ Change Approved Program❑ SuspenCI Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension ❑ Operations Shutdown Re-enter Susp.Well ❑ Stimulate❑ Alter Casing❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: City of Akutan Exploratory ❑✓ Development ❑ 210-073 r 3.Address:3380 C Street,Suite 205,Anchorage,AK,99503Stratigraphic ❑ Service ❑ 6.API Number: 50-295-20004-00 1 7.If perforating: 8.Well Name and Number: i'11-43 What Regulation or Conservation Order governs well spacing in this pool? Tom' f- F W W E.l L ' 1 y 4 $1'b1i3 Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): Fee, 10.Field/Pool(s): Hot Springs Bay Valley /i Descriptive Summary of Abandonment Proposal: The City of Akutan proposes to abandon two temperarature gradient wells,TG-2 and TG-4, in the following manner: 12 ppg cement will be pumped into the wells through the hang-down liners currently set in both wells and back up the annulus between the hand-down and the open hole and cemented casings. The estimated pumping pressure for the complete circulation of Well TG-2 is 390 psi at 0.5 bbls per minute, and 590 psi at 0.5 bbls per minute for Well TG-4. Well TG-4 showed no signs of permeability and most of the permeable zones in TG-2 have been cemented behind casing, full cement returns to surface are expected. Should cement returns fail to be sufficient, additional cement will be bullheaded until good cement is at surface. Following that,the wellheads will be cut off at 4 feet below ground level, cover plates will be welded on, and the remnants buried. All activities will be documented with photographs and daily reports. Page 1 of 1 Schwartz, Guy L (DOA) From: Alan Bailey [alanbailey@geothermalresourcegroup.com] Sent: Thursday, July 05, 2012 2:34 PM To: Schwartz, Guy L (DOA) Cc: R Mann Subject: TG Well Abandonment at Akutan 1 Attachments: Akutan Well 2 and 4 Abandonments.docx .Z0 —07! Guy, 2-40 While the City of Akutan is doing some summer field work,and with a helicopter available I would like to abandon the two TG wells that were drilled in 2010. I've attached cross sections of both wells. Both have 1.66 tubing hung down from surface. In the case of the shallow, "Hot Springs"well,there is a zone at 746'that produces hot water,and I think that zone should be put behind cement. Ideally, I would like to pump cement from surface so that there is at least 100 linear feet of cement in the casing x tubing annulus from surface,the pump cement through tubing to plug off the zone and get cement to the last casing shoe. f. /On With the TG-4 well,which is tight, I would like to get cement 100'over the bottom of the tubing,then squeeze from surface to get cement from 100' back to surface. In both cases, I would like to leave cement in the tubing rather than pull it. al'`' If you are available next week, I would like to give you a call. Alan Bailey Manager of Engineering Geothermal Resource Group, Inc. alanbailey@geothermalresourcegroup.com 760-341-0186 Office 760-341-9673 Fax 775-304-3253 Cell www.geothermalresourcegroup.com 7/5/2012 Akutan TG-4 A 11 "South Elbow"Well 6-5/8" Conductor at 3/' `% -S Fully Cemented — 07 3 0.25WI Casing at 186' 1 � T Fully Cemented � bG rr'b�• SQL LY 1( 1 C" 615 V 3-Y2 0.25W1 Casing at 596' 0 M � I s� 3.01" Open !iole to 1500' 1.660" 2.4ppf I ubing, Hung from Surface to 1491' a n --� k ADDENDUM Akutan Geothermal Resource Assessment July 22, 2011 By Amanda Kolker,AK Geothermal Alan Bailey, Geothermal Resource Group Cc) i \CA Ck \k �t laa _ ��IYvI ADDENDUM:Akutan Geothermal Resource Assessment Summary On June 30, 2011, a report was submitted to the City of Akutan entitled the "Akutan Geothermal Resource Assessment."This report recommended the targeting the upflow zone,with chemically benign fluids and temperatures approaching 572 °F (300 °C), for geothermal energy production. This zone appears to exist at >6000' depths below the 1500 ft2 (0.5 km2) fumarole field. Unfortunately, this zone cannot be reached by a vertical well due to steep and hazardous terrain, and will have to be targeted via directional wells across the fumarole field. An important unresolved issue in the June 30 report was the trade-off between the cost and practicality of constructing a pad at high elevations (closer to the target) but with difficult access, versus drilling from the valley (further from the target) from an area with easier access. A recent site visit by an experienced drilling engineer has, unfortunately, not completely clarified this issue. The site visit did identify two areas—one in the valley and one at high elevation near the fumarole field—that could both potentially host wellpads and facilities. However, there are problems associated with both options. First, there is some uncertainty about the suitability of the valley wellpad sites that are within reach of the upflow target. Also, the valley option requires 3200' of horizontal offset from the wellpad, requiring a highly engineered directional drilling operation(s). The high elevation option is also a challenge as it requires additional road up steep terrain. Despite these challenges,either solution appears feasible. Pending detailed economic and technical evaluation of these two options, the valley option is now considered preferable based on the many advantages of valley-based project development. The other alternative should continue to be examined in case the valley option turns out to be less economically attractive and in case production needs to be augmented with further drilling in the future. Site Visit Findings, July 2011 On July 8-13, drilling engineer Steve Nygaard (Geothermal Resource Group) and Akutan Geothermal Project Logistics Manager Bob Kirkman (RMA Consulting) made a visit to the geothermal area. The purpose of the investigation was to verify the feasibility of drilling pads, access roads, base camp, and power plant facilities in the following general areas: 1. Hot Springs Bay Valley(HSBV). The main objective in the valley was to investigate how close to the fumarole target a wellpad could be sited from the valley side. The issue is a creekbed with banks that gradually steepen towards the target. 2. Fumarole field.The team was to investigate whether there was sufficient flat ground at high elevation (>900') near the fumarole field to site a wellpad, base camp, and plant facilities. The team was also to investigate the best option for road access to the fumarole field area. 2 ADDENDUM: Akutan Geothermal Resource Assessment Hot Springs Bay Valley 1. Wellpads and welifield design The July field team identified 3 sites in the northwest corner of the valley—V1-A,V1-B,V1-C—that could potentially reach the proposed target via directional drilling. These sites follow Fumarole creek up towards the target and get successively closer with V1-C being the closest. However,these locations will require a substantial degree of site preparation, including cut and fill operations for the wellpads and possibly the road;slope stabilization;stream diversion; and possibly additional site mitigation. In addition to the site concerns, another problem with valley-based drilling operations is that the proposed wellpad that is closest to the target — site V1-C — is still offset from the target by 3200' or greater. This is of concern because drilling directionally to achieve a horizontal offset of 3200' poses several technical challenges that could quickly escalate drilling costs. First, to reach a target of 6500' below mean sea level (MSL), a deviated well with 3200' horizontal offset would have a measured depth of over 7700', escalating drilling costs. Second, V1-C must achieve an angle of 33.50/ 100 ft.to reach the target, but such an angle will likely make pumping the well impossible. This would be a problem if well does not flow. Fig. 1 shows a map and calculated trajectories of deviated wells towards several targets (upflow, outflow, and/or a fault with downflow for reinjection purposes). , .... N.'"-...i...-•"/ 1 ( r__-=-.. Ai _______ literz/ ,,,ir; c\i;,.--,,,,...,...,,,....: k, \\,..,.., / /., �� r i ! ''" 1-..,. —0- h60.--,... ....:=,,,,,,;:,,,,,..../../,.. ....." . 1 j / irpol - ' ri c Thic" I 1 I , 2 a ml -r. - 1111"-_Jii:,4111 -//: CS -,a. ‘ 6...$.0....,,\s....„...qp ... 0, C:\........., __...,:Z.,.... ..,......... .............er 'N**'‘. '''%''N‘•4 \ 1:2' ,, ,..op d II P i'7'..et r''...'' ' i 0.' _)1, I Imo! _ I "'���`'=: -r -..".N. \ \<2::-----"N -.\i---\----).‘..."";,-.." .\\\ '...:.s\\\-—...,,::Nt'-., -Os,":\ ' ill/4 4,-- __,-.- ''''i \\ . , Figure 1. Map showing wellpad sites V1-A, V1-B, and V1-C, with a plant location at site 1. Annotations show distance to target and max. deviation angle(e.g., maximum deviation for a well drilled from site 1C is 33.5%100 ft. to obtain a lateral distance of 3200'). Assumptions: each well will be drilled to 6500' below MSL, each well is deviated(directional)with trajectories are based on a target 6500 below MSL. 3 ADDENDUM: Akutan Geothermal Resource Assessment Road access and facilities The road access to the valley sites V1-A and V1-B is straightforward. According to Steve Nygaard, "Without a doubt the best technical solution would be to extend the harbor road over Saddleback to site 1. It would be cheaper and faster to build, especially if you could get started using the equipment currently on the harbor construction building site (save on mobilization costs). With the direct road from town, you wouldn't need to build much of a base camp..." The road from Akutan Harbor to sites V1-A and V1-B would run about 4 miles. Locating the power plant, base camp and other facilities is also straightforward for the valley sites. As shown in Fig. 1, the plant and other facilities could be sited just east of the wellpad(s). It is uncertain at this time whether a road could be constructed to wellpad V1-C. According to S. Nygaard, "After alternate site 1 C, the cost to build the road would escalate appreciably due to the steep slope of the canyon but doable (if the hillside formation is stable enough)... A geotechnical geologist or civil engineer would have to confirm that the hillside is stable enough to cut a path into it." Fumarole Field 1. Wellpads and wellfield design The field team identified one site suitable for one or more wellpads, camp, and plant facilities near the fumaroles. Steve Nygaard noted that "it wouldn't be that difficult to construct a drilling pad on either side of the fumaroles." An area of relatively flat ground was located to the west of the fumarole area, at site labeled F-A. Site WS-3 (relabeled F-B) was judged inaccessible based on poor road options (Fig. 2). f77 ' w 1 4 ;' 00 ),.,, , B� j,�(�y .,M. 1-1 .f. _ �W .w-. w w_ F-A i a ITT" � �� y - ice. < '' _ , cci., w 474,,,' oar o .► :.,r/ 1 i cam. . .� Figure 2. Map showing the location of wellpad site F-A relative to the other proposed sites. The 19-acre area outlined in blue appears to be suitable for wellpad and other facilities. The site labeled WS3 is no longer being considered due to access issues. 4 ADDENDUM: Akutan Geothermal Resource Assessment The 19+ acres of relatively flat ridge line shown in Fig. 2 is attractive from the point of view of site development as well as from a drilling and resource perspective.This area merits further investigation as an alternative to the valley sites. Road access and facilities B. Kirkman identified a route up to site F-A from HSBV, ascending from a location near slimhole well TG- 4 (blue circle in Fig 2). As in the proposed route to sites V1-A-C, the road to access site F-A would begin at Akutan Harbor and cross the saddle into HSBV. At the western end of HSBV, instead of turning north it would continue up a gradual hill to the east and then north towards site F-A.This route is marked by a white path in Figs. 2 and 3. Reaching the ridge line may be challenging, as there are steep intervals which would require building switchbacks,and the site is roughly twice the distance from the 2010 camp location. This route would have an estimated length of about 4.5 miles from Akutan Harbor. Hence,this area will require an additional—1/2 mile of road from HSBV, compared to sites V1-A-C. ._, 1 ,--173 - —::.---- N- ''''''4.47,. - N ',, ! 7),/,..--*I'ili'll \ i t lb- 111114%.'411 s, ' rie" ..,,,,,. _,,i;T II/ t171(---"/ Lit'sL1/4.'"64=,..i..1*-'\'' r- •r't ' -%,- -7,......... Driti , ''''IP,Vr ; . , --*-1K.„..7.1‘07. 411111116111111M-- -- \-.:\\ ,,N-7-`` ..'"---%—_, __. ------ -. it vili 1,4 . 1 , . . , 4 . ,..... ., , , 1 .......... Aik.,,„, ,,,,„..„ . 0,- Otr"Trz-z--- I 04,,, .,,,`",yk ' l'' le I 1 t'tl� 171t_.,,�f i�X .,..�ir! . Figure 3. Map showing the location of wellpad site F-A relative to the other proposed sites, courtesy of B. Kirkman. This location would be suitable for wellpad and other facilities. The site labeled WS3 is no longer being considered due to access issues. Another alternative investigated during the site visit was access from the north side of HSBV to sites near the fumarole field. The field team followed a route from the second cove on Hot Springs Bay; however,they did not recommend it, noting that the terrain steepens quickly. 5 ADDENDUM:Akutan Geothermal Resource Assessment Drilling plan and wellfield design From a resource perspective, drilling closer to the target from sites F-A or F-B is preferable. The probability of success will be higher because the wellpad is closer to the target, and because the trajectory appears to cross one or more faults at near-perpendicular angles, rather than subparallel angles (Fig.4). 6002 - .W T i fl` ,w. ..,M .. ii: .. - . i y 4 Ohn ,G • i ry II F-B 150 i of r n -200 t` 150 0 I 6001 47`��� ' 120• tat I'S-- :0„) , Ns , —4 50 1 • 15 12 6000 ��ohn F� /�•` V ` .Q Lig V1-C,B,A ` k.„,. .. . ,4 7 75 • TG4 5999 `;�:\ 1So"C • 0 _\ 0p.,•C • • . f� 5 .L 441,jSpm :x z 5998 — .-.:.. .- ,. -iii f I 440 441 411 443 444 4.0 0 1 2 +� Mapped Isotherm j Akutan Geothermal Project Km •°. fault 50°C Interval -- ---- -- - WnbrnG•eo 3D MT 22S•p-2009-Cumming G•esei•ne• Arn Theral Gradient �, Inferred Isotherm Resistivity Cross-section CM2(UTM km WGSB4) YY well . . fault25°C interval (_-.. Figure 4. Map showing of proposed wellpads (white circles with crosshair) and well trajectories (white arrows), overlain on resistivity data for 400m below sea level. Isotherms show temperatures at 400m below sea level corresponding to conceptual model 2 (line CM2; see Resource Assessment for details) with outflow beneath the mountain to the north of HSBV.Also shown are mapped and inferred fault traces. However, the recent site evaluation suggests that a wellpad could be sited in HSBV within reach of the upflow target at location V1-C. Due to several advantages of geothermal development in the HSBV, this option is favored at the present time. A logical approach would be to begin by drilling at site V1-C and then making a decision whether to drill at V1-A or V1-B based on the drilling results. However, further engineering and economic evaluations of all sites must occur before a final decision is made. The location of reinjection wells is unresolved at this time. This is because the reservoir geometry is still unconstrained due to lack of subsurface data near the fumaroles. Understanding reservoir geometry is important because it is easy to "miss the target" with reinjection. Hence, additional exploration and drilling data are needed to constrain the reinjection site. 6 ADDENDUM:Akutan Geothermal Resource Assessment Conclusions The next phase of drilling on Akutan will target the upflow resource, with temperatures anticipated between 428-572 °F (220-300 °C). A recent evaluation of the access and drilling issues involved in targeting a well on the upflow resource has identified a provisional direction for future drilling efforts. However, a financial evaluation of the two options has not been performed.A detailed evaluation of the following issues must be conducted before a final decision is made: 1. Cost of engineering a wellpad at Site V1-C. 2. Cost of engineering a wellpad at Site F-A. 3. Cost of drilling directionally 3200' from site V1-C to a TVD of 6500' beneath the upflow target, plus evaluation of associated issues (rig type and availability, transportability of rig, ability to pump well,etc.) 4. Cost of drilling directionally 1200' from site V1-C to a TVD of 6500' beneath the upflow target, plus evaluation of associated issues. 5. Cost of building a road to site V1-C from Akutan Harbor. 6. Cost of building a road to site F-A from Akutan Harbor. 7. Evaluation of environmental impact of road and pad alternatives. Pending the above information, the next phase of drilling will provisionally be staged in Hot Springs Bay Valley, with wellpads located at the top of the valley and boreholes aimed directionally beneath the upflow area. If the valley wellpad sites, upon further evaluation, are deemed unsuitable or too expensive, or if the valley wells do not produce sufficiently for power production, drilling should instead be staged at a high-elevation site just west of the fumarole field. The 19+ acres of relatively flat ridge line near site F-A is attractive from the point of view of site development as well as from a drilling and resource perspective. Reaching the ridge line may be challenging, but increased road construction cost may be allayed by reduced pad construction costs and, perhaps more significantly, decreased drilling costs.This area merits further investigation as an alternative to the valley sites. At this time, it is recommended that permit applications for drilling be submitted for no less than ten sites, listed below.Additional sites may be identified upon review of aerial photography(pending). 1. V1-C1 2. V1-C2 3. V1-B1 4. V1-B2 5. V1-A1 6. V1-A2 7. F-Al 8. F-A2 9. F-B1 10. F-B2 In addition to the financial evaluation described above, additional exploration prior to drilling should focus on identifying faults and evaluating their control on the upflow system. This could upgrade the valley wellpad sites by extending the target southeastward from the fumaroles. It will also provide parameters useful in planning trajectories for both production and reinjection. 7 Page 1of1 Schwartz, Guy L (DOA) From: Alan Bailey [alanbailey©geothermalresourcegroup.com] Sent: Thursday, July 05, 2012 2:34 PM To: Schwartz, Guy L (DOA) Cc: R Mann Subject: TG Well Abandonment at Akutan Attachments: Akutan Well 2 and 4 Abandonments.docx ..710 -071 Guy, Z(O — o75 While the City of Akutan is doing some summer field work,and with a helicopter available I would like to abandon the two TG wells that were drilled in 2010. I've attached cross sections of both wells. Both have 1.66 tubing hung down from surface. In the case of the shallow, "Hot Springs"well,there is a zone at 746'that produces hot water,and I think that zone should be put behind cement. Ideally, I would like to pump cement from surface so that there is at least 100 linear feet of cement in the casing x tubing annulus from surface,the pump cement through tubing to plug off the zone and get cement to the last casing shoe. -t- (UO With the TG-4 well,which is tight, I would like to get cement 100'over the bottom of the tubing,then squeeze from surface to get cement from 100' back to surface. In both cases, I would like to leave cement in the tubing rather than pull it. alF If you are available next week, I would like to give you a call. Alan Bailey Manager of Engineering Geothermal Resource Group, Inc. alanbailey@geothermalresourcegroup.com 760-341-0186 Office 760-341-9673 Fax 775-304-3253 Cell www.geothermalresourcegroup.com a ^off --- • 3- 0-o' Akutan Geothermal Resource Assessment Commissioned by City of Akutan, Alaska As part of its Geothermal Development Project June 2011 11 ! x. s►,.,.... ... . i ‘, , 4 15(y. ,, ,, _ ,; kr) 1/14-. .. , ,, , - i , . ,, f . e','; i' ' ' ' • - i ''''‘ Principal Investigator: Amanda Kolker,AK Geothermal Other Investigators: Bill Cumming, Cumming Geoscience Pete Stelling, Western Washington University David Rohrs, Rohrs Consulting Akutan Geothermal Resource Assessment Contents Summary 3 Objectives of Study 3 Introduction 4 Background and Previous Studies 4 Geologic Setting 5 Geothermics 7 MT Resistivity 7 New Data 2011 8 1. Temperature Gradient Data 8 la.Core Hole Drilling 8 lb. End-of-Well Logs 9 lc. Equilibrated TG Logs 10 ld. P/T Data Analysis 13 2. New fluid chemistry and geothermometry 15 2a.Sample Collection and Data Sources 15 2b.Chemistry 15 2c.Geothermometry 15 2d.Geochemical Model 16 3. Core data 16 3a.Overview 16 3b. Rock Types and Primary Mineralogy 17 3c.Secondary Mineralogy, Mineral Paragenesis,and Hydrothermal History 17 3d. Permeability and Porosity of Well Rocks 20 Resource Conceptual Models 21 Future Drilling Targets 25 Capacity Assessment 27 Resource Existence and Size 27 Confidence in Resource Existence 27 Probable Resource Capacity 28 An alternative approach 28 Monte Carlo Heat-in-Place Option 28 Resource Risks 29 Upflow Development Risks 29 Outflow Development Risks 30 Conclusions 30 Recommendations 31 References and Bibliography 32 2 Akutan Geothermal Resource Assessment Summary The Akutan geothermal resource can be conceptualized as containing two major zones: an upflow zone and an outflow zone. While the outflow and upflow zones likely represent one interconnected field, they are distinguished here for the purposes of development. The upflow zone temperatures could approach 572 °F (300 °C), and the reservoir probably consists of a brine liquid overlain by a small steam cap.The outflow zone temperatures are lower, decreasing as the brine flows eastward. Fluids produced by corehole TG-2 show evidence of chemical re-equilibration to lower temperatures, with cation geothermometry providing a range from 392-464 °F (200-240 °C). The outflow fluids become extensively mixed with cooler meteoric waters near the surface hot springs. Alteration mineralogy in exploratory coreholes suggests two disappointing conclusions about the outflow system: (1) the rocks in both TG-2 and TG-4 were at temperatures greater than 469 °F (250 °C) ✓ in the geological past and have cooled to present temperatures; and (2) the part of the outflow encountered by the wells appears to lack sufficient thickness and permeability to support commercial ✓ development. Additionally, development of the shallow outflow would entail significant risk of rapid cooling during exploitation as a result of either cold water influx from near-surface aquifers or injection breakthrough. Exploratory corehole drilling encountered the outflow zone with fluid temperatures of 359 °F (182 °C) at shallow depths of 585' (187 m). Recent data suggests that the 359 °F (182 °C) zone produced in TG-2 is drawn from a nearby fault zone not located directly below the well. Although it is possible that a hotter resource may exist slightly deeper than either of the current wells, this is unlikely to be the lowest risk target for development. Although TG-2 encountered the outflow predicted near its location, the two exploration coreholes did not demonstrate an outflow resource that would be suitable for development. Given these drilling outcomes and results of new gas geothermometry from the fumaroles, a well targeted to cross the 1500 ft2 (0.5 km2) fumarole field would have the highest probability of encountering commercial production at Akutan.This target is likely to be >428°F(>220°C)and could be as hot as 572°F(300 C).The depth to the target will depend on the elevation of the drill pad but it is likely to be greater than 4000' (1300m). An important issue is the trade-off between the cost and practicality of constructing a pad closer to the fumarole and drilling further directionally. A 380-428 °F (180-200 °C) outflow resource target about 2200' (800 m) to the northwest of TG-2 might be preferred if its higher targeting risk and lower generation per well were sufficiently offset by lower drilling and access cost. Objectives of Study This study has three primary objectives: (1) to report on data collection efforts for the Akutan geothermal resource to date; (2) to provide the technical parameters needed when assessing the feasibility of developing the geothermal resource for a combined heat-and-power project envisioned by the City of Akutan and other stakeholders; and (3)to provide well targets for future drilling efforts. This report synthesizes all the datasets collected on the Akutan geothermal field to date (listed on p. 4), and provides an updated assessment of the Akutan geothermal resource based on all available data. Well targets and recommendations for mitigating resource risks are given. 3 Akutan Geothermal Resource Assessment Introduction Akutan Island is located 790 mi (1271 km) southwest of Anchorage and 30 mi (48 km) east of Dutch Harbor. The Island is home to North America's largest seafood processing plant. The City of Akutan and the fishing industry have a combined peak demand of^'7-8 MWe which is currently supplied by diesel fuel. In 2008,the base cost of power in the City of Akutan was$0.323/kWh (Kolker and Mann,2009). Since 2008, the City of Akutan has led exploration and other assessment activities in an effort to determine the feasibility of geothermal development on the island. The 2009 exploration program included practical access assessments, a geologic reconnaissance field study, soil and soil gas geochemical surveys, a remote sensing study using satellite data, a review of existing hot springs geochemistry data, a magnetotelluric (MT) survey, and a conceptual model analysis. The 2010 exploratory drilling program included the drilling of slim-hole temperature gradient (TG) wells, fumarole sampling, and chemical analysis of well and fumarole fluids. Follow-up production-size wells are being planned for the near future. Background and Previous Studies As a volcanic island with accessible hot springs, Akutan has been the subject of geothermal resource studies since 1979. The original exploration effort was limited to the immediate hot springs area and included geologic mapping, shallow (<500' / 150m) geophysical surveys, and fluid geochemical studies. In summer 2009, the COA executed a follow-on exploration program including a geologic reconnaissance field study, soil and soil gas geochemical surveys, a remote sensing study using satellite data, a review of existing hot springs geochemistry data, a magnetotelluric (MT) survey, and a conceptual model analysis. In summer 2010, an exploration drilling program was carried out with two temperature gradient (TG) wells drilled in Hot Springs Bay Valley (HSBV). The following reports have been written on the Akutan geothermal resource, in chronologic order: 1. Motyka, R., and C. Nye, eds., 1988. A geological, geochemical, and geophysical survey of the geothermal resources at Hot Springs Bay Valley, Akutan Island, Alaska. Alaska Division of Geological and Geophysical Surveys (ADGGS), Report of Investigations 88-3. 2. Motyka, R.J., S. Liss, C. Nye, and M. Moorman, 1993. "Geothermal Resources of the Aleutian Arc."Alaska Division of Geological and Geophysical Surveys (ADGGS) Professional Paper 114. 3. Kolker and Mann, 2009. "Heating up the Economy with Geothermal Energy:A Multi-Component Sustainable Development Project at Akutan,AK."Transactions,Geothermal Resources Council Annual Meeting 2009. *Both paper and poster format available. 4. Kolker, Cumming,Stelling, Prakash,and Kleinholtz, 2009. "Akutan Geothermal Project: Report on 2009 Exploration Activities." Unpublished report to City of Akutan and the Alaska Energy Authority,37p. 5. WesternGeco, 2009. Magnetotelluric Survey at HSBV, Akutan, Alaska: Final Report — 3D Resistivity Inversion Modeling. Unpublished report prepared for the City of Akutan, Alaska, GEOSYSTEM/WesternGeco EM, Milan, Italy, 27p. 4 Akutan Geothermal Resource Assessment 6. Kolker,Stelling, and Cumming, 2010. "Akutan Geothermal Project: Preliminary Technical Feasibility Report." Unpublished report to City of Akutan and the Alaska Energy Authority, 31p. 7. Kolker, Bailey,and Howard,2010. " Preliminary Summary of Findings:Akutan Exploratory Drilling Program." Unpublished report to City of Akutan and the Alaska Energy Authority,32p. 8. Kolker,Cumming,and Stelling, 2010.Geothermal Exploration at Akutan,AK: Favorable Indications for a High-Enthalpy Hydrothermal Resource Near a Remote Market."Transactions, Geothermal Resources Council Annual Meeting 2010. *Both paper and poster format available. 9. Rohrs, 2011. "Geochemistry of the Akutan Geothermal Prospect,Alaska." Unpublished report to City of Akutan, 36p. 10. Stelling and Kent,2011. "Akutan Geothermal Exploration Project:Geological Analysis of Drill Core from Geothermal Gradient Wells TG-2 and TG-4." Unpublished report to City of Akutan, 24p. 11. Kolker, Bailey,and Howard, 2011. "The 2010 Akutan Exploratory Drilling Program-Preliminary Findings." Draft paper submitted to the Geothermal Resources Council for publication/presentation at the GRC Annual Meeting,October 2011. 12. Kolker et al, 2011. "Akutan Geothermal Project:Summary of Findings from the 2010 Drilling Program." Unpublished report to the City of Akutan,33p. Geologic Setting g Akutan volcano is part of the Aleutian Volcanic Arc, which is Alaska's most promising setting for geothermal energy.Akutan volcano is one of the most active volcanoes in the Aleutians,with 32 historic eruptions (Simkin and Siebert, 1994). Akutan volcano is a composite stratovolcano with a summit caldera ^'1 1/4 mi (2 km) across and 200-1200' deep (60-365 m; Newhall and Dzurisin, 1988; Miller et al., 1998). Most of the reported eruptions included small-to-moderate explosions from the active intracaldera cone. An initial volcanic hazard review indicated that the proposed geothermal development area was unlikely to be directly impacted by eruption activity consistent with the previous 1500 years,excepting ash fall that might cause temporary closure. The HSBV walls are composed of—1.4 Ma lava flows,with the SE wall being slightly older and containing numerous dikes. The valley was glacially carved, perhaps during the last major glaciation ending "8,000 years ago, and potentially reworked during a minor glacial event ending 3,000 BP (Black, 1975). The HSBV is composed of two linear valleys (the SE-trending Fumarole Valley and the NE-trending valley that contains the hot springs; Fig. 1) joined at right angles, suggesting structural control of glacial flow. Soil geochemical anomalies (Arsenic (As), mercury (Hg), and carbon dioxide (CO2) at the junction of the Fumarole Valley and the HSBV also suggest that the valley junction is structurally controlled and could be an important fluid conduit (Kolker et al, 2010). Hg, As and CO2 occur in anomalously high concentrations near the hot springs as well. 5 Akutan Geothermal Resource Assessment In March 1996, a swarm of volcano-tectonic earthquakes (>3000 felt by local residents, Mm„ = 5.1) beneath Akutan Island produced extensive ground cracks but no eruption of Akutan volcano. InSAR images that span the time of the swarm reveal complex island-wide deformation, suggesting inflation of the western part of the island and relative subsidence of the eastern part. The axis of the deformation approximately aligns with new ground cracks on the western part of the island and with Holocene normal faults that were reactivated during the swarm on the eastern part of the island.The deformation is thought to result from the emplacement of a shallow, east-west-trending, north-dipping dike plus inflation of a deep magma body beneath the volcano (Lu et al., 2000). Studies of 3He/4He ratios in Akutan fumarole gasses indicate degassing of relatively fresh near-surface magma (>6 RC/RA; Symonds et al., 2003). This implies that unlike many other composite stratovolcanoes, Akutan's magmatic plumbing system includes two lateral rift zones, similar to the classic rift zones at Hawaiian volcanoes and elsewhere. These rift zones are aligned along the regional least-compressive-stress axis (John Power, pers. comm.), and serve as active magmatic conduits at shallow crustal depths (Fig. 1). NW- trending rifting appears to be providing the large-scale permeability as well as the magmatic heat source -crucial for the development of an extensive hydrothermal reservoir beneath the volcano. 166'47W 166.97 165'56'0 165'5277 165'48V"W 54'12714 1 �•... _ ... #- - - r 1 0.5 0 1 2 3 141ornete'4. -.i 1 ` "4 1 05 0 1 2 3Miles + N H -_ t-.. i', y---+k e �. - r3r sy 1 1^A Ii `a tfur. rRE H. 4, N, 54.8'0" jl'i l., _ I v' T „,�ys. _ :i.+ ' r k=„ b y F. e - „300,- '.,„.„ z , , 4-. . , s f ll , , , 0„, ,,l� utan village ge .rbc 4 ; . e,&A l {, y . . .,.,, { k ` t ; < Legend ' 54'40" ii IO Geothermal project area H r Rp u 1 ;'',i .; , • Hot springs ',,,e'.,',' , r 4 _Fumarole area + 4 „`'• ----- Fault lines -',,, ,,,,,0:::,,:--.;.-,,---,:i < s _ -*-x±1,1 'f'" ?t ,,� n Raft zones i r y�\ Ksr s 113 f "07.40...- ;j2r F 166.0'017 165'567W 165'527W 165'48'0"W 165'44'0"YV Figure 1. Topographic map of Akutan Island,showing the geothermal project area and pertinent geologic features. Hot Springs Bay Valley(HSBV)is an L-shaped topographic low that lies at the center of the geothermal project area. 6 Akutan Geothermal Resource Assessment Geothermics Several thermal springs are located in HSBV, about 6 km from Akutan village (Fig. 1). Five groups of hot springs with about ten vents have been identified, including tidewater springs on Hot Springs Bay beach that are only exposed at low tide. Temperatures range from 129 to 205 °F (54 to 96°C); and some have been reported as boiling. A fumarole complex (often called the "fumarole field") exists at the head of HSBV to the west of the hot springs and covers an area of approximately 1600 ft2(500m2). Motyka and Nye (1988) concluded that the fumaroles are likely fed directly by gases and steam boiling off the deep hot reservoir and that these fluids then mix with cool groundwaters to produce the hot spring waters further down the valley, forming a geothermal system that is at least 2.4 mi (4 km) long. Recent studies of the chemical composition of the fluids confirm that they become extensively mixed with cooler meteoric waters near the surface. Fumarole gas geothermometry indicates that the reservoir fluids attained a temperature of at least 518°F (270°C). Cation chemistry from the hot springs and produced fluids indicates that the fluids are re-equilibrating to lower temperatures along the outflow path, with cation geothermometry from the fluids produced by corehole TG-2 providing temperatures of 211-232 °C. The silica geothermometry of 320 °F (^'160 °C) indicates that the resource close to the hot springs (probably<1500'/<500m distance and depth) is likely to be 320-358 °F (160 to 180 °C) (Rohrs, 2011). This is consistent with active silica sinter deposition at the hottest springs. Based on the springs, well TG-2 was expected to encounter a permeable zone with 320-358 °F (160-180 °C) fluid,which it did. The structure(s) controlling upflow of hydrothermal fluids is probably one or more NW-trending normal fault(s). One such mapped fault cuts near-perpendicularly across HSBV (Fig. 2). All of the hot springs are topographically lower than the fault's surface trace, consistent with geochemical indications that they outflow from an upflow near the fumarole. The fumarole field lies along a parallel linear feature, but no fault has been mapped there. A perpendicular NE-trending fault may control the linear shape of the hot spring locations, but that fault has not been conclusively identified with available data. MT Resistivity The resistivity pattern of the Akutan geothermal prospect has an overall geometry similar to that of most geothermal reservoirs where a low resistivity, low permeability smectite clay caps a higher resistivity, higher temperature, permeable geothermal reservoir. However, the resistivity values of>20 ohm-m within the low resistivity zone at Akutan are much higher than in the smectite zone of most developed geothermal fields. Several models can explain such a pattern, including an unusually high fraction of dense lavas causing weak alteration, or relict alteration that formed at higher temperatures. A localized pattern of alteration near the hot springs is more conventional, with a <600' (<200 m)thick, 5-15 ohm-m zone that represents a smectite clay cap overlying a higher resistivity geothermal outflow (Figs. 10-13).Therefore,the overall resistivity geometry is consistent with the geochemistry. A tongue of high resistivity at -300 m elevation in Figs. 10-13 trends from the fumarole to the hot springs. This is consistent with a relatively resistive flow path that originates from a >428 °F (>220 °C) upflow near the fumarole to a 358-428°F(180-220°C)outflow extending to the hot springs. Unfortunately, steep topography and high winds prevented the MT from accessing much of the prospective area. There are no MT stations over the fumarole area and so a well that targets an interpreted upflow in its vicinity might target only the surface extent of the altered ground and 7 Akutan Geothermal Resource Assessment fumaroles. There are also no MT stations over a large part of the likely outflow path, making it difficult to assess the risk of targeting a well on the accessible part of the likely north flank of the outflow. New Data 2011 1. Temperature Gradient Data la.Core Hole Drilling In 2010, two small-diameter temperature gradient ("TG") core holes were drilled at locations given in Fig. 2. Since the Akutan Geothermal area is roadless, the drilling operations were supported by helicopter. Due to budget constraints,only two of the four planned holes were actually drilled;these are marked with black arrows in Fig. 2. The 2010 exploratory drilling plan was designed to test whether the shallow resource was potentially commercial. Within narrow budget constraints, the wells were designed for long-term monitoring as well as a test of the shallow, accessible targets at the Akutan geothermal field. The hole(s) were completed as temperature gradient wells and available for future monitoring. A detailed report on the drilling operations, P/T survey results, and other data is provided in Kolker et al. (2011). Well "TG-2" was drilled to a TVD (total vertical depth) of 833' (254 m). It was sited to test the outflow aquifer(s). Between 585 and 587'(178 and 179 m), a highly permeable zone was encountered that flowed geothermal fluid at 182 °C (359 °F). This productive zone was cased and cemented, sealing it off, at which point it cooled to about 329°F (165 °C).The structure hosting the flowing fluid appeared to be a fractured, highly vesicular, flow margin. Due to the temperature and permeability of the formation at relatively shallow depths,drilling this well was challenging. Although targeted to 1500' (457 m),the well was terminated due to drilling problems. Well "TG-4" was drilled to the planned TVD of 1500'. It was sited at the southern part of the junction between the two perpendicular valleys, to test the size and extent of the outflow zone. Since well TG-4 did not encounter substantial fluid flow, its location appears to be outside the margins of the outflow zone,vertically or horizontally (or both). However,well TG-4 did encounter an anomalously high shallow temperature gradient, implying close proximity to a geothermal source. 8 Akutan Geothermal Resource Assessment la 4.... AFI .�`'.' �,,�.,.,.,, ofele f 6\ ' 'a X33 T f Affitk, ',--, - 4g...410."—iiL_ Ithigattc ""�JA i'lh fA il iv ...,....4 '''' ' ' 5 Wr fC'efi i 36T , ,, \, ..., _ , . w....,,,, _ 1 .... .,_,....„.., )#1 �,�►a � liar . / �._ : fA! ••- i ..let‘ 4 `�`\ • \`-` J. 1.4 y �""`w'w., . , / x• • .;_r"' 7.71: —„1..%• -".,arae lik. s( s it / .C( ss/onll v..L, . \ . . • - .-.- . . -\ f t .1 : '\,, 'j 1rr' ii /8 T s" r..0,411, ,� . Miles . Fumaroles ,. II 0.25 0.5 1 15 2 ,r Well Location rj Meter- ^� t���"`�f Ii 250 500 1.000 •1.500 2,000 1__- Z ,�+` _ - r • Hot sprang . \\ .� ‘J.••-Transmission Lines lapprox. 5)Akutan proiect are - Figure 2. Map of the Akutan Geothermal area, showing the four candidate exploration well locations that were considered for the 2010 program. The two holes drilled in 2010 are marked with black arrows. lb. End-of-Well Logs After TD was reached, three P/T logs were recorded at 12, 24, and 36 hours after circulation ended for each well. For every run, stops were made at 20 foot stations. Because these surveys were taken so soon after the well was drilled, the temperature readings were still influenced by the cooling effects of fluid circulation. Therefore these represent "unequilibrated" downhole temperatures. In order to predict the equilibrated downhole reservoir temperature, we used the Horner method to extrapolate the measured values to a longer period. The end-of-well elevation vs. temperature plot generated from extrapolated Horner values is shown in Fig. 3. The MRT reading from the flowing zone is also shown as a purple dot. 9 Akutan Geothermal Resource Assessment Akutan TG Well Temperatures(F) 0 100 200 300 400 500 200 -i 0 _ -200 - -400 — J • cu -600 c -800 - "' -1000 — - TG2 -1200 TG4 —Boiling Curve 0.1%NCG -1400 Flowing MRT TG2 -1600 Figure 3. Estimated equilibrated Temp v. depth plot for TG-2, based on Horner extrapolations of downhole survey data(see Fig.11 and text for details). Both wells show very high shallow temperature gradients,which is consistent with their proximity to the shallow outflow zone. Following production,TG-2 shows a drop in temperature occurring just above the casing shoe at 603' (181 m), corresponding to the hot fracture zone between 585 and 587' (178 and 179 m) that was cemented in. The apparent cooling is likely the result of drilling fluid and cement injected across that entire area. TG-4 shows a relatively rapidly increasing temperature gradient until ^'900' (274 m), transitioning to a slowly increasing temperature gradient from 900'-1500'. The fact that there was no temperature reversal and that the gradient continues to increase suggest there could be a deeper, hotter aquifer below 1500' (457 m) that was not penetrated by drilling. An injection test performed on well TG-4 suggested that the well has generally poor permeability. 1c.Equilibrated TG Logs While the end-of-well surveys were conducted with a memory tool, it was not possible to use a memory type tool for the post-completion logging due to the small inner diameter of the Akutan TG wells (inner diameter > 1.5 inches / 3.81 cm). Due to this and other unique conditions of Akutan TG wells (high 10 Akutan Geothermal Resource Assessment temperatures at shallow depths, remoteness of the wellsites, among others), thermistor-type temperature logging equipment was used,and downhole pressures were not recorded. The survey for TG-2 was completed on May 22, 2011. Results from the equilibrated survey are shown with the three build-up surveys in Fig.4. Akutan TG2 Temperatures,°F 0 -- 100 100 -- —— _ — — -- 200 300 — -- J a 400 a, a, c 500 — — --— 0 fa ar, 600 700 — -12h 08-2010 __ y —24h 08-2011 800 - —36h 08-2011 May-11 900 -i T 0 50 100 150 200 250 300 350 400 Figure 4. Equilibrated temperature profile for TG-2,plotted with the three end-of-well heat-up surveys. The end-of- well surveys were taken 12 hours.24 hours,and 36 hours after circulation;the equilibrated profile was obtained 9 months later in May 2011. The new temperature profile shows a distinctly different shape from the end-of-well temperature build- up profiles. Among the new features to note are: (1) The well was bleeding while the log was run, resulting in a minor steam or two-phase section in the upper 60-70' (20-25 m). (2) Apparent cooling of the well since shut-in is noticeable in the upper 400' (122m). This probably reflects a trickle of water downflowing from around 200' (61m) MD and exiting into the formation at about 415' (126m) MD. It can only be a trickle of water because the water is heating up as it flows down behind the casing. (3) The highest temperatures occur in the permeable zone near 585' MD (415' / 126m elevation), with a temperature reversal of about 9°F (5 °C) below the permeable zone to the bottom of the well. 11 Akutan Geothermal Resource Assessment The new data also shows that the permeable zone at 585' MD (415'/ 126 m elevation) has fully recovered in temperature. Notably,the static temperatures measured in this permeable zone are about 338 °F (170 °C), which is lower than the 359 °F (182 °C) temperature measured in this zone when the well was flowing. Since the MRT reading does appear to be correct based on silica geothermometry,this implies that the well was drawing in higher temperature fluids when it was producing. A temperature survey was run in TG-4 by the City of Akutan crew on May 10, 2011 (Fig. 5). Akutan TG4 Temperatures,°F -200 0 -.—_---._._ _ 200 ---- -- - 400 -- J Q 600 v 800 0 1000 a, W 1200 12h 08-2011 -24h 08-2011 1400 36h 08-2011 -May-11 1600 r 0 50 100 150 200 250 300 350 Figure 5. Equilibrated temperature profile for TG-4,plotted with the three end-of-well heat-up surveys. The temperature profile from the equilibrated survey differs very slightly from the end-of-well temperature profile. The new profile shows that the top 800' (244 m) of well TG-4 heated up slightly, but the bottom temperatures remained extremely close to those measured during the end-of-well surveys.This is not surprising in light of the fact that that well was relatively impermeable and exhibits a temperature profile that shows heating primarily from conduction for the upper 800' (244 m). By contrast, the bottom of the hole is approaching an isothermal gradient. This suggests that the conductive heating is from the side (i.e.,from a shallow outflow zone at some lateral distance), not from a hot aquifer below. 12 Akutan Geothermal Resource Assessment 1d.P/T Data Analysis Although TG-2 flowed geothermal fluid at 359 °F (182 °C) during drilling, the equilibrated temperature logs show a maximum temperature of 338 °F (165 °C) with a reversal at the bottom of the hole. This implies that the 359 F fluid was not circulating in the immediate vicinity of TG-2 but rather was "pulled in" from elsewhere due to the pressure drop caused by flowing the well. A likely scenario is that the productive subhorizontal fracture at 585' (178m) in TG-2 is connected to a subvertical fracture dipping west (see Fig 11). When the subhorizontal fracture was produced, the subvertical one became a temporary conduit for fluids in the outflow zone. It is unlikely that the source of the 359°F (182 °C)fluid is directly below Well TG-2 because of the temperature reversal recorded in the most recent log. A comparison of the static temperature profiles in TG-2 and TG-4 shows the difference between the shape of a convectively heated outflow profile in TG-2, and a conductively heated temperature profile in TG-4 (Figure 6).Also,the temperatures in the upper 800' (254 m) of TG-4 are generally lower than in TG- 2, indicating that TG-4 is further from the shallow outflow path. No strong conclusions can be drawn from the temperature profiles as to whether additional high temperature permeable zones underlie either well, but it appears unlikely based on the shape of the bottom of both well profiles. Akutan TG Well Temperatures May 2011 (°F) -200 - 0 — — 200 — — — -- 400 J a 600 --- a) a) 800 a, 1000 W 1200 -TG2-05-2011 -TG4-05-2011 1400 Boiling 0.1%NCG 1600 i r 150 200 250 300 350 400 450 Figure 6. Equilibrated well profiles for both Akutan TG wells, shown with a boiling point with depth curve for water with 0.1%non-condensable gas content. 13 Akutan Geothermal Resource Assessment The 359 °F (182 °C) temperature measurement during drilling of TG-2 does appear to be correct based on silica geothermometry. If the well was drawing in higher temperature fluids when it was producing, this suggests that TG-2 was drilled on the margins of a more permeable and hotter outflow path. The higher temperature fluids drawn into TG-2 during the flow test suggest that the production zone is in proximity to the higher temperature zone but that it has a relatively low permeability connection to this zone. The slight temperature reversal of about 9 °F (5 °C) below the permeable zone is consistent with the geologic model that the thermal features in HSBV represent a confined lateral outflow from a geothermal reservoir located further west,or possibly north. The temperature gradients for Akutan wells TG2 and TG4 vary widely, but compared to the continental average of 1.65 °F/ft (30 °C/ km; Fig. 7) they are very high above 600' (244 m). This suggests that both are within proximity of a very shallow outflowing resource. Akutan Well Temperature Gradients(T2-Tv°F) • • •. t•• • • 200 •• •• . • , /11• • 400 •�■ ' C I 600 ! .*. < 800 • • a •,f 1000 • O •• • • 1200 i2 ■TG2 a) w •TG4 1400 -- ■ Average continental 1600 0 2 4 6 8 10 12 14 16 18 Figure 7. Temperature gradients, in degrees Fahrenheit per foot,for both Akutan TG wells. The average continental geothermal gradient of 1.65 °F/ft is shown for comparison. The outlier data point at-410'depth can be ignored as it reflects a transition between the part of the well affected by a small amount of downflowing water and the part unaffected,and thus does not represent an accurate temperature gradient. 14 Akutan Geothermal Resource Assessment 2. New fluid chemistry and geothermometry 2a.Sample Collection and Data Sources Two fluid samples were obtained from well TG-2, with the first obtained from the entry zone at 585'- 587' (178-189m) measured depth (MD) during a well discharge. This production zone was subsequently cased off. A second flow test of the well obtained samples from production zones between 603' (184m) and 833' (245m) MD, which was the completion depth of the core hole. Because TG-4 encountered poor permeability conditions, a sample of the fluids in the wellbore was obtained by flowing with an air assist. The MD of TG-4 was 1500' (457m) and had a cemented casing at 596' (182m) MD. Therefore the data obtained during the discharge of the wells vary in quality. New gas chemical data are from samples obtained from the fumaroles in 2010. All other analyses used in geothermometry calculations and chemical modeling were obtained from past reports (fluid analyses from the hot springs, non-condensable gas analyses from the summit fumarole and from the hot springs —see p.4 for sources). 2b.Chemistry Geochemical data were interpreted using a combination of binary and ternary diagrams and geothermometry gas plots. The data set used to interpret the reservoir conditions consists of all of the data obtained at Akutan. Data and interpretations are provided in full in Rohrs(2011). The chemical analyses of the hot springs water shows that they are derived from a dilute, near-neutral Na-Cl reservoir brine. The Akutan hot springs show slightly elevated HCO3- and SO4 concentrations, suggesting mixing along the outflow path with dilute, steam-heated near-surface waters. Hydrogen and oxygen isotopic data shows that the hot spring waters are derived from local meteoric water. The chemistry of the fumarole gasses demonstrates a strong magmatic affiliation. There is no evidence from the gasses that the reservoir water has mixed with air-saturated fluids along an outflow path. Compared to many geothermal systems, Akutan displays enriched N2 concentrations, which in some cases would raise concerns with regards to acid or vapor-cored conditions in the reservoir. However,the other gas plots show that the gases are well-equilibrated and likely to be derived from a high temperature neutral chloride reservoir. In addition, the gas concentrations in the flank fumaroles imply that some fraction of gas is derived from equilibrated steam, indicating the presence of a localized steam cap in the reservoir. The chemistry of the fumaroles are consistent with an equilibrated geothermal system associated with an andesitic stratovolcano (Giggenbach, 1991). In comparison, the gas from the summit fumarole originates from a more oxidizing environment and exhibits high H2S concentrations.These all suggest a magmatic affiliation for the summit fumarole steam. 2c.Geothermometry The hot spring and well discharge samples are well suited to chemical geothermometry using the silica and Na, K, Ca, and Mg concentrations of the fluids. The estimated temperature of last equilibration along the outflow path suggests that the fluids have equilibrated at ^'338 °F (^'170 °C) and ^392 °F (200 15 Akutan Geothermal Resource Assessment °C) for the two samples from TG-2. This temperature is similar to the estimated entry temperature of 359°F (182°C) at 585-587' (178-179m) MD in well TG-2 (Kolker et al, 2010). Cation concentrations in hot spring and well discharge analyses show that the springs and well fluids are mixed or partially equilibrated fluids. This is commonly observed along outflow paths where the fluids are re-equilibrating to lower temperatures and mixing with near surface waters with elevated Mg concentrations (Rohrs, 2011). The data from hot spring HS-A3 and the entry at 585' (178 m) MD in core hole TG-2 suggest that the fluids originate in a deeper reservoir with temperatures in the range of 428-464 °F (220-240 °C). This compares to a temperature of 412 °F (211°C) estimated from the Na-K-Ca geothermometer for the well discharge. Geothermometers that apply Na, K, Ca, and Mg concentrations tend to partially re-equilibrate to lower temperatures in the outflow zone, and so the deep reservoir temperature is likely to exceed 464°F (240°C; Rohrs, 2011). Geothermometry estimates from flank fumarole gasses exhibits very good consistency, indicating an origin from a mature, equilibrated neutral chloride reservoir. The gas geothermometry consistently suggests reservoir temperatures of 518-572°F(270-300°C; Rohrs, 2011). 2d.Geochemical Model The new geochemical data set confirms the previous interpretations of the resource distribution in HSBV. The hot springs represent a shallow outflow from a high temperature neutral chloride reservoir that exists further west. The chemistry of the hot springs indicates that they have experienced significant mixing with cooler, dilute near surface meteoric waters. Because the fumarole gases show little evidence of mixing with air-saturated waters, the upflow zone is likely to lie near the fumaroles. Also, gas grid plots indicate that the fumaroles contain a component of equilibrated steam, suggesting the possibility that a localized steam cap overlies the deeper geothermal reservoir. Geothermometry of the well discharges and the fumarole gases indicate a likely deep reservoir temperature of at least 464 °F (240°C) based on Na/K geothermometry,with temperatures possibly as high as 572°F (300°C) in the upflow based on gas geothermometry. The geochemical data do not provide any constraints on the reservoir boundaries to the west nor on the reservoir volume within the outflow area (Rohrs, 2011). The non-condensable gas data from the fumaroles suggest that a steam cap may overlie the deep brine reservoir. The chloride hot springs in HSBV represent shallow outflow from the reservoir. The outflow becomes diluted by mixing with cool meteoric waters, especially in the near surface environment (Rohrs, 2011). Thus, the geochemical data are very consistent with the geochemical outflow models suggested by Kolker et al. (2009). 3. Core data 3a.Overview Composite logs from Akutan TG wells TG-2 and TG-4 of the bulk lithologies, alteration mineralogy, and temperature data are provided in Appendix A. Full lithologic logs were recorded at the wellsite during drilling and are provided as an Appendix in the Summary of Drilling Findings (Kolker et al., 2011). The core was then sent to Western Washington University (Bellingham, WA)for detailed laboratory analysis. / 16 Akutan Geothermal Resource Assessment The goal of the laboratory analysis was to determine the hydrothermal history of the HSBV. Core samples were selected based on zones of interest from drilling records, core photographs, and complete coverage of the depth of core. Determination of specific mineral species was conducted through X-ray Diffraction (XRD) analysis, Scanning Electron Microscopy (SEM), and petrographic observations. Quantitative permeability studies of the core were not conducted, however qualitative observations about the permeability of the field by visual observations of the core were recorded. Finally, compositional analysis of 19 bulk rock samples were conducted by X-ray Fluorescence (XRF) at the Geoanalytical lab at Washington State University in Pullman, WA. Methodologies for above studies, detailed results, and discussions are provided in Stelling and Kent(2011). 3b.Rock Types and Primary Mineralogy There are four main lithologies present in the Akutan core: basalt, andesite, ash tuff, and "lithic basalt." The most common lithology in the core is basalt lava. These flows appear to be subareal in nature and contain plagioclase, clinopyroxene, rare olivine and primary apatite. The ash tuffs are fine grained rocks lacking phenocrysts. Groundmass phases are plagioclase microliter, glass, and alteration minerals (see below). In TG-2, these units are <3' (1 m) thick. In TG-4, which is ^'2 miles (3.2 km) closer to Akutan Volcano,similar units are as thick as 60' (18 m). The rocks provisionally named "lithic basalt" were a puzzle during the on-site evaluation, and remain enigmatic. The lithic basalt is composed of multiple different rock types, suggestive of some sort of debris flow deposit, yet the matrix between the clasts is crystalline, indicating a magmatic origin. At this time,the origin of this lithology is unknown. 3c.Secondary Mineralogy, Mineral Paragenesis,and Hydrothermal History A graphical representation of secondary mineralization and clay replacement is presented in Stelling and Kent (2011). The rocks in general appear to be only weakly altered. As a result of the increased porosity near lava flow tops, these regions tend to be more altered and more readily brecciated than the main body of the lava. Heavy Fe-oxidation was observed between flow layers. Alteration minerals occurred interstitially, in fractures, in vesicles,and in contact zones. Alteration assemblages in both wells are dominated by chlorite, zeolites, epidote, prehnite and calcite, and this alteration appears to have happened multiple times in both wells. The presence of adularia in specific locations in both wells indicates higher temperature and permeability conditions existed at some point in the past. The presence of kaolinite in TG-2 indicates argillic alteration with lesser extent and intensity. Illite was identified in both wells,although much more sparsely in TG-2. Within the most recent propylitic alteration event in TG-2, the sequence of zeolite formation shows a classic trend toward higher temperatures with depth. It is likely that this trend will continue below the base of the well (833' / 254 m). Figure 8 shows that some higher-temperature minerals (illite, epidote, prehnite, wairakite and adularia) occur in regions that are currently much colder than expected for these minerals. This suggests that the TG-2 region underwent higher temperature alteration in the past. The presence of these higher-temperature minerals at unexpectedly shallow depths further suggests that a significant portion of this older alteration sequence has been removed through erosion, possibly 17 Akutan Geothermal Resource Assessment glacial. Overprinting of these minerals by lower-temperature alteration assemblages indicates the sampled region has since returned to a lower-temperature alteration regime with reduced permeability. HSB 2 Well Temperature(°C) Meters0 50 100 150 200 Feet i i "Heu Smectite —0/ 1st CPt ''illit liIt it 100 Smectite —.0 `,. _— "/ lst Yug 50 j f __ r% % 1"Chab ' 1 00 1"Ep,Pre i F--4 - 300 No — )1,.. ,`r st 1st Adu . Smectite + t < __ ai+. 400 1 0 g it Adu:Adularia Chab:Chabazite 150 --- —._ Cptl:Clinoptilolite 'e, Ep:Epidote 500 • Heu:Heulandite il Smectite Lau:Laumontite ,or Pre:Prehnite PO2'A"casing shoe j Wai:Wairakite _ 600 Yug:Yugawarilite I40' 200 ; ' —♦—Temp 12 hours heating i —A—Temp 24 hours heating I Smectite ' --II--Temp 36 hours heating I� 700 { .: Temp 48 hours heating nit Ilt j 1 0 Temp 271 Days heating 250 --a—BPD Temp 800 I t Figure 8.First occurrence of indicator minerals with depth in core from Akutan well TG-2. Horizontal arrows indicate formation temperature ranges for each mineral. Dashed lines indicate published values;solid lines indicate the most commonly reported minimum temperatures. The pattern of alteration in TG-4 is more complex than TG-2 (Fig. 9). That the depositional history of TG- 4 includes multiple alteration events does not necessarily mean that the two wells have had significantly different thermal histories; rather,the most recent alteration event may have been stronger in the TG-2 region, overprinting more completely the alteration sequence observed in TG-4. 18 Akutan Geothermal Resource Assessment HSB 4 11e0.101 Temperature(°C) • 0 50 150 200 Meters Feet 0 — —' 0 0 0 0 1sChab _ O O - 0 50 Smectite H 15SCptl Q - - 1 Adu L O 15t Yug ' ♦— 200 Smectite ' Q � i E 1) 5t Lau 1005-1 Mord ♦ 9___ — E-- --15tEp ♦1tlllite ,` r 400 1'tHeu 150 -- 15tAnal Smectite ,. Smectite 1 r 600 "c ' 2%"casing shoe ` 0 200 , — — `•' 0 '" 0 V E " 0 r 0 a Smectite - O o 0 - so0 0 250 0 —__- 0 ,,0 :• • • • • 300 0 1000 • 350 1"Pre Adu:Adularia -f 1200 Anal:Analcime • Chab:Chabazite • Cptl:Clinoptilolite -*--Temp heating 12 hrs • • 400 Ep:Epidote -A-Temp heating 24 • hrs Heu:Heulandite -II-Temp heating 36 hrs 00 Ep(strong) E — f Lau:Laumontite 1 0 Mord:Mordenite 0 Temp heating 260 days 0 1400 Pre:Prehnite 1 -*—BPD Temp 0 O Yug:Yugawarilite 0 0 450 Figure 9. First occurrence of indicator minerals with depth in core from Akutan well TG-4. Horizontal arrows indicate formation temperature ranges for each mineral. Dashed lines indicate published values;solid lines indicate the most commonly reported minimum temperatures. 19 Akutan Geothermal Resource Assessment Comparing the observations made in the two drill cores provides a basic sequence of alteration for the HSBV geothermal outflow zone. Both cores show an alteration sequence progressing from an early propylitic event, a narrow band of adularia-bearing propylitic alteration, followed by a later propylitic event. The trend from moderate propylitic to high-temperature adularia-forming alteration and back to moderate propylitic indicates that the shallow portion of the HSB field has reached its thermal peak and has cooled moderately. Additionally, many of the higher temperature minerals occur at depths much shallower than reported in other geothermal fields. Thus is it likely that 1)this region was hotter than it is currently, and 2) the uppermost portion of the rock column has been removed and these rocks have risen to their modern shallow depths. 3d. Permeability and Porosity of Well Rocks The primary lithologies do not lend themselves to high primary permeability.The abundance of isolated vugs filled with secondary minerals indicates that fluid flow through microscopic intergranular networks has been important, but flow rates are likely very low. Vug filling is especially common in fine-grained, detrital deposits (e.g., ash tuff), but clay alteration and fracture mineralization by carbonates and zeolites reduces permeability in these rocks. The primary fluid pathways appear to be associated with brittle fracturing and lithologic contacts, based on the abundance and degree of alteration and secondary mineralization. Very fine grained deposits (ash tuff) lack large crystals that would add structural control over the fracture patterns. As a result, these rocks are prone to planar fractures at prescribed orientations (30°, 45°, 60°and 90°).The majority of these fractures have some sort of secondary mineralization associated with them, and some of the larger fractures are deeply altered to a variety of clays and other minerals. Because the tuff is more susceptible to clay alteration, these fractures can seal before major secondary mineralization becomes intense. However,these units are not very thick in the wells,so may not have extensive control over the overall fluid flow in the reservoir. Permeability may locally increase at the top of lava flows where vugs in vesicle-rich flow tops may collapse, but this was not observed in the core. Some heterogeneous lithologies (e.g., "lithic basalt," see below) contain entrained clasts of older material. Fluid flow within these lithologies are concentrated and directed around the entrained clasts,which would likely result in moderately increased permeability compared to intergranular flow. The occurrence of the mineral adularia helps to elucidate the permeability. Although adularia occurs in all lithologies in the HSB cores, the restriction of adularia to fractures highlights the importance of secondary permeability, as it does in many fields worldwide. Adularia is strongly associated with zones that once had high permeability but each occurrence of adularia in the core is in veins that are now thoroughly sealed by mineralization. Therefore, the waxing of a higher temperature system and V subsequent waning has apparently reduced the permeability in the HSBV outflow system. No evidence for large scale structures were encountered in Akutan geothermal wells. A number of brecciated zones were observed in TG-4, but most were "sealed" with secondary mineral deposits and therefore probably do not represent active faults. Minor slickensides observed in cores could be related to a possible normal fault on the SW side of the valley near TG-4. 20 Akutan Geothermal Resource Assessment Resource Conceptual Models Several conceptual models of the Akutan Geothermal Resource were presented in an earlier report (Kolker et al, 2009). The acquisition of new data in 2010-2011 are consistent with the same basic upflow - outflow model. The most important change in the conceptual model assessment is the increase in confidence in the fumarole as the locus of a benign reservoir upflow that would be a suitable target, based on the promising new gas geochemistry analyses. The new data significantly reduces the probability that an economic reservoir would be found in HSBV. The location of the high permeability outflow path is still only loosely characterized by two models, although the upflow seems more closely connected to TG-2 than to TG-4. The alternative outflow pathways continue to be either along the HSBV or along a northern trajectory from the fumaroles to the hot springs.These two alternatives are explored in Figs. 10-13. Both conceptual models are based on the notion that the Akutan geothermal system is a single resource comprised of two distinct features: a high-temperature (>500 °F/ >240 °C) upflow zone, and a lower-temperature outflow aquifer (^'360-390 °F/ 180-200°C), as suggested by chemical data. • r.r A053 ,•�° A•,t 6002 r,b _ Ar V A Oc Aoog n0,0 .��g.. • • • i • Ar Ohm.m ArlO • • • 200 / �\ %,.% • i� 150 ... i 120 6001_r—,---_—. ),,,, , 100 iG n^,F. • t— 70 .1 r \.r C70 a • _ �} 3 4 ....VT, ) • / 40f4 30 i 0 • 20 •Itr •' • '�' jr' ♦ �A , i 15 . _ ` ,• ♦ I ! 12 0 •• O / • 6000 s 1 _ • 17 I. �s, /4 1ST • • • • - .. "c TG4 5999 t \\;, 7O0. t SO , S „C • 5998 `�. 't�".J'1 i:.. r ,v 1 I I I 1 I 440 441 4.1. 4.1 44a 445 446 o 1 2 `Mapped Isotherm Akutan Geothermal Project i Km fault SO"C interval -----1 WesternGeco 3D MT 22-Sep-2009 -Cumming Geoseieno•1 Thermal Gradient • Inferred Isotherm -1 well ,mss fault 25'C interval Resistivity Cross-section CM1(UTM km WGS84y11 Figure 10. Map view of"Conceptual model 1,"showing outflow along HSBV. Isotherm contour placement is based on downhole temperature data, chemical geothermometry, hot springs and fumarole locations, and MT resistivity data(shown here at-300 m(-984 ft)depth). Profile line "CM1"corresponds to Fig. 11. 21 Akutan Geothermal Resource Assessment 800 ex Fumerole R aao - TG4 TG2 � } O z 200-50€ T a a� .T`' �2` ` 1s c s0 ... I 200- lrttttrr9;N , , °r _- -400 -600 to �S ,o C s++ tt1 800- ( • • . i / E locoJJ ♦` N N. C 1200- 1 • -1400- 1 �\ �♦ r `v�` -1800 �/ \ ♦4 11 ` �,. �v -2000- $' f, '~-- ` '' C " , -2200- • ....... .. ` -2400- • • -2800- •• `....... -2800 Nic'fi -3000 - 0 1 2 3 a 5 8 Distance(Km) Reslstmty(Ohm m)0 50 20 10 �flowter Gradient en al Well 50°C Isotherm 120 f 1 0 20 [1 10 5 depth slice Fault(dashed Isotherm Akutan Geothermal Project - for map a where inferred) 25°C Interval WasternO.co 30 MT 22-Sap-2009 •Cumming Oaoseisnoa Resistivity Cross-section CM1 (uTM km WGS84) Figure 11. Profile"CM1,"as shown in Fig. 10. This model shows outflow along HSBV. Isotherm contours based on downhole temperature data, chemical geothermometry,hot springs and fumarole locations,and MT resistivity data(shown here as 3D inversion model). Conceptual model 'CM1'(Figs. 10 and 11) shows a high temperature resource upflowing beneath the fumarole field, and cooling along an outflow path that follows the L-shaped path of HSBV. The upflow must be some lateral and vertical distance from well TG-4, since no trace of conductive heating from a deep source was observed in the temperature profile of TG-4. Also, for this model to fit the observed downhole temperature profiles in both wells, the outflow along HSBV can only be very thin (vertically constrained low-permeability)and restricted to the shallow subsurface. Because the 359 °F (182 °C) flow during the flow test completed while drilling is higher than the measured static temperature, because there does not appear to be a downflow that would reduce the temperature of this zone from 359°F (182°C)to 338°F (165 °C)when the well is static,and because the temperature reversal in TG-2 below this zone makes upflow from below the well unlikely,the produced higher temperature fluid appears to have been "pulled in" laterally from a nearby source.This could be related to the westward-dipping fault near TG-2 shown in Figs. 11 and 13. The rapidity with which this hotter fluid was drawn in during such a short test implies that the 338 °F (165°C) permeable zone in TG- 2 must be restricted in volume and at a higher natural state pressure than the 359 °F (182 °C) adjacent reservoir. 22 Akutan Geothermal Resource Assessment Ii 6002 ,, 50.. s i 1 ,'.,, ,,,,,.\-4. wr G x,50 _ .. 6001 .�'� - 1'5 r e ,yds: ,. i 6000 , . ,' �, . 7 75'C '�` 3C,• � ♦ r 5999 t„.„,,,,, ) , ., ♦ 1 1 7 00 C ... O 5998 '.... AIMEMMIL , , I I 440 441 442 443 444 445 446 Mapped Isotherm Akutan Geothermal Project fault 50'C interval — -- Km WnbrnG♦eo 3D MT 22.S.p-2003-Cumming Gwul♦nw hThermalGradient �,, Inferred IsothermResistivity Cross-section CM2(UTM km WGS84) Y well • fault 25°C Interval Figure 12. Map view of"Conceptual model 2,"showing outflow beneath the mountain to the north of FISBV. Isotherm contour placement is based on downhole temperature data,chemical geothermometry, hot springs and fumarole locations, and MT resistivity data(shown here at-300 m(^'984 ft)depth). Profile line "CM2"corresponds to Fig. 13. Conceptual model 1 'CM1'does not resolve the location of a hotter outflow resource of 360-392°F (180- 200 °C), for which there is a substantial amount of geochemical evidence. Therefore, an alternative model is proposed called 'CM2' (Figs. 12 and 13). In CM2, the shallow outflow path takes a northerly trajectory from the fumarole to the ENE towards the hot springs, circumventing HSBV altogether. This model appears more likely based on several lines of reasoning: 1) the temperature profile for TG-4 shows no evidence for being along an outflow path, implying that outflow feeding the hot springs is laterally distal;2) a low-resistivity clay cap appears to form a dome pattern around the northerly outflow path,which is consistent with the interpretation that the HSBV is near, but not in,the main outflow path of geothermal fluids (Figs. 10 and 12); and 3) the isotherm contours on the CM2 profile (Fig. 13) are slightly more typical of an outflowing geothermal system. 23 Akutan Geothermal Resource Assessment BOO 600 400 200 i 'NIIIIIIIII -200 4S0 I . _.:,- -400 -600 $� f uj t0 -800 � -r+�� J , � 1000 1. I �.., f C i C- 1200 ,e, t O 115' N \ >-1400 it %.`4, W-1600 yd. ��. l 1, \\ �+,m„ .. -1800 N \\ r . 1 \ -2000 11, \ 40 -ICSk -2200 1,' ‘ -2400 \ \‘2, ` -2600 �� ti........ "1 -2800 '5 \C, -3000 `` ``�` 0 1 2 4 5 Distance(Km)3 Ohm.m120 i 50 !! 20 i t 40 15 7 Hofowtater Gradient Well 50°C Interval t. Thermal Isotherm 1p 100I 200 t 30 12 20 0 15 depth slice I Fault(dashed Isotherm Akutan Geothermal Project — for map a where inferred) 25°C interval WestemGeco 3D MT 22-Sep-2008-Cumming Geoscience — / Resistivity Cross-section CM2(UTM km WGse4) Figure 13. Cross section of profile line"CM2,"as shown in Fig.12. This model shows outflow beneath the mountain north of HSBV. Isotherm contours based on downhole temperature data and chemical geothermometry, MT resistivity data, hot springs and fumarole locations,and fault lines. Both models suggest that producing the outflow resource would be very risky, both because of the generally low permeability expected based on several lines of reasoning and also because there is no well-developed clay cap to indicate that a large-very permeable reservoir volume at —360-390 °F (180- 220 °C) exists under HSBV. The lack of widespread surface alteration, geochemical, and ground temperature anomalies (Kolker et al., 2009) in HSBV are consistent with this interpretation.Additionally, the chemical composition of the hot springs fluids suggests that outflow fluids become extensively mixed with cooler meteoric waters near the surface, raising concerns about cold water influx into the outflow system with production. While the conceptual models of the outflow resource have downgraded its potential for development, geochemical data from the fumaroles significantly upgrades the fumarolic area as a drilling target. The fumarole data suggest that the flank fumarole field lies in fairly close proximity to an upflow zone from the reservoir, that a steam cap may overlie the upflow, and that reservoir temperatures could approach 570 °F (300 °C) within the upflow. The deep reservoir probably consists of a brine liquid capped by a small two-phase region (steam cap) (Rohrs, 2011). Resistivity data suggest that the upflow reservoir is situated in brittle rocks, implying propylitic alteration regime and a good possibility of high permeability. 24 Akutan Geothermal Resource Assessment Future Drilling Targets The two types of resource targets represent two development options for the AGP: 1) The upflow resource has a high exploration risk, but potentially low development risk and high output capacity. 2) The outflow resource has potentially easier access but higher exploration risk, and presents several development risks, including a lower output capacity per well. The highest priority target for future drilling is at the upflow resource, due to the following factors: (1) Evidence of commercial-grade permeability due to the presence of fumaroles that are chemically connected to a neutral-chloride reservoir with a steam cap. (2) The fumarole gas geothermometry indicates that the source fluids are likely to be being equilibrated to a temperature of >572 °F (>270 °C). These temperatures could exist directly beneath the fumaroles. Alternatively, if the upflow originates further west, the fumaroles may mark the location where the outflow first encounters boiling conditions. In this case, temperatures beneath the fumaroles could be in the range of 428-464°C(220-240°C). (3) As the highest-enthalpy target, the fumarole area could be expanded to meet additional power demand if it should ever present itself (e.g., new industrial capacity, larger scale secondary use,etc.) The exploration data suggests that the likely upflow location is in the general vicinity of the fumarole. However, the fumarole is located -1150' (^350 m) up a very steep hillside, posing access limitations. Hence, an important issue is the trade-off between the cost and practicality of constructing a pad closer to the fumarole and drilling further directionally. A small rig may only be able to achieve a very modest directional offset, but a rig capable of greater directional offset would be several times more expensive. Two alternative surface locations have been sited to target the high priority upflow zone. Regardless of the pad location, the well should be targeted to at least 4500' (1350m) MD and preferably to 6000' (1800 m) MD. The first, preferred alternative "A" is located near the fumarole field (Fig. 14). This is closest to the high temperature upflow zone. Access to this location could be via a road running east-west which skirts the mountain to the north of HSBV. Such a road appears to be buildable at less than 3 miles (6 km)from Hot Springs Bay access, but would require dock facilities to be built at the beach. However, this access option raises the question of transmission to Trident and Akutan Village. It also raises questions about volcanic hazards(see 'Risks'section, below). The second, less preferable alternative is located in the Fumarole Valley >2/3 mi (^'1 km) southeast of the fumarole field (Fig. 14). A directional well drilled from this location (called "Well-1" in past reports) beneath the fumarolic features or to the north beneath the local resistivity high may intersect the upflow zone. From pad location "B", the margins of the upflow resource would be targeted via directional drilling and the outflow resource could be targeted via vertical drilling. However, limitations 25 Akutan Geothermal Resource Assessment on directional drilling may not allow the target to be reached from pad location "B." Hence,this wellpad location is riskier than alternative "A." A determination on this issue should be solicited from a qualified geothermal drilling engineer before a final decision is made. l "4 rte'• .►..— -; tia ( .,.-! .fi` 1a r;� /\ A. , d`A.- ROPoiM •• Rdye t '' K `` �� �� ( � ' `\\ ` _ �oL 4377; cou, .. �� •c`a �.I. t• :ate sssT7 4.r' 7:/ �4 _. , i ( .' 'wit \‘ '-'111 !...*i, rkkira-gAlik—'°"--1r;---1;1•11.4.0- + ( S.4 ' .-716 7 Ak - '- ,0 k ki/ t 1 .: 1ti1�rr/j� ub 1 i - t, r ,-• -_ -./J . moi— 4 a1 tler �r - 0 �: :- \ Akutan Figure 14. Map showing possi. e we pad locations to target the Akutan upflow resource (blue triangles). Each pad could host two wells—a directional well aimed towards the fumarole field(knobbed black line), and a vertical well. Possible road alignments to the wellpads are shown in red. Also shown are the three sections recently selected by the Akutan Corporation for subsurface ownership rights in a land swap agreement with the Aleut Corporation. Should drilling at sites A and B fail, or if developing the upflow resource is not possible, subsequent pad locations could be sited to target other parts of the outflow zone. A 380 to 428 °F (180 to 220 °C) outflow resource target about 2200' (800 m) to the northwest of TG-2 might be preferred if its higher targeting risk and lower generation per well due to its lower temperature were sufficiently offset by lower drilling and access cost. Prior to generating outflow targets, additional exploration activities should be undertaken to target the hottest and most permeable part of the outflow resource. This would likely require additional subsurface imaging work using one or several geophysical techniques. It would also probably require additional slimhole drilling and/or deepening of TG-2. Since the casing in TG-2 was not cemented in place, it could be retrieved it and the well deepened by 1000' (300m)or more. 26 Akutan Geothermal Resource Assessment Capacity Assessment As summarized by Glassley (2008), different approaches and methodologies to geothermal resource capacity assessment have given rise to a broad range of results that are not directly comparable. Hence, the outcomes of resource assessments are sensitive to the methodology and assumptions employed in the analysis, and different studies often produce widely different estimates of a resource. The assessment of reserves by analogy used in previous Akutan reports is updated here based on the results of the wells and the fumarole gas geochemistry. The approach applied here is to use analogies to a few published examples in order to highlight important similarities and differences with respect to Akutan. Resource Existence and Size Resource risk assessment approaches commonly divide the assessment into two parts; 1)an assessment of confidence in the existence of a resource as a percent probability, and, 2) assuming the resource exists, an assessment of its size, usually as a statistical distribution (e.g. Newendorp and Schuyler, 2000). The probability of existence is sometimes restated as the probability of exploration success; i.e., the probability that an exploration drilling program would discover at least one economically productive well. In many published geothermal resource assessments, the assessment of existence is often not explicitly evaluated but nominally included in the size distribution, for example, in the Western Governors' Association (2006), Clean and Diversified Energy Initiative Geothermal Task Force Report. In this report, many geothermal prospects in the western USA with poorer indications of temperature over 220°C and much lower surface heat flow than Akutan are assessed as having over 20 MW potential. Confidence in Resource Existence The most common method of estimating the probability of existence for a resource is to have a group of experts review the available data and, based on analogous experience with other geothermal prospect areas, estimate the confidence (as a probability) that the necessary components of a resource exist together. For volcanic prospects that have hot springs with cation geothermometry similar to Akutan's and a non-magmatic fumarole, few failure cases exist in which the most attractive target was drilled. With respect to the earlier assessments of Akutan, the very minor magmatic indications and excellent gas geothermometer estimates of resource temperature have increased confidence in the existence of a high enthalpy resource. The numerous geothermal success cases differ in detail, particularly with respect to the geology and very dilute chemistry characteristic of Akutan. For example, in the Americas there are several developed geothermal fields in volcanic systems with different geologic settings but broadly similar liquid and/or gas geochemistry. The 572 °F (270 °C) San Jacinto Field in Nicaragua has 10 MW installed and 72 MW under development. It has roughly analogous fumarole gas geochemistry and a similar area of intense alteration, although the resistivity of its clay cap is much lower, more like a conventional geothermal field.The 320 to 350°F (160 to 175 °C), —40 MW Casa Diablo field at Long Valley(Sorey et al., 1991) and the 320 to 360 °F (160 to 180 °C), 45 MW Steamboat Springs Field near Reno (Mariner and Janik, 1995) have liquid chemistry similar to Akutan, but again, a lower resistivity clay cap. At Akutan, the combination of a non-magmatic flank fumarole with excellent gas geothermometry over 518°F (275°C), a trend in cation geothermometry to >428 °F (>220°C), silica geothermometry over 320°F (160°C) with 27 Akutan Geothermal Resource Assessment sinter deposition proven to exist in the subsurface by a well support the existence of a convecting geothermal resource on Akutan with a high confidence of 80%. Probable Resource Capacity The capacity of the geothermal resource at Akutan in terms of electrical power can be assessed using analogies, both the rough comparisons to the prospect estimates provided in the Western Governors' Association report and the analogs to the 20 to 72 MW San Jacinto development and the 40 to 45 MW Casa Diablo and Steamboat Springs developments. Because of the dilute outflow chemistry and low permeability relict alteration at Akutan, handicapping the Akutan likely 320 to 358 °F (160 to 180 °C) outflow resource by 75% relative to these developed reservoirs would be reasonable, giving an analogous low temperature resource capacity estimate of 15 MW with a 66% probability. Because a high temperature resource very likely exists, a more optimistic capacity estimate for the entire system would be like San Jacinto, 10 to 72 MW with a 66% handicap because of its high clay cap resistivity and difficult access, this results in a risk weighted estimate of about 20 MW. Using the Western Governors' Association report assessments as analogs,an assessment as high as 100 MW seems reasonable. An alternative approach An output capacity for the 359 °F (182 °C)fluids produced by TG-2 was estimated in 2010 based on the flowing temperature of the well and assumptions about flow rate (Kolker et al., 2011). Based on then- available information, it was estimated that a production well drilled at or near the TG-2 site could produce 1.34 MW up to a maximum of 2.38 MW. However, recent data and analyses including the stabilized temperature curves, alteration mineralogy from cored rocks, have supported revisions of the earlier assumptions used for estimating wellhead flow capacity were optimistic. Monte Carlo Heat-in-Place Option In previous reports on Akutan (Kolker, 2010), the heat-in-place method has been outlined but it has not been formally applied. Initially developed by the USGS for rough regional estimates (Muffler, 1979), more elaborate Monte Carlo versions of the method have recently been adopted by stock exchange regulators in Australia and Canada as a standard for publishing geothermal reserves (Lawless, J., 2010). Despite its common use by geothermal investors, as detailed by Garg and Combs (2010) and more generally considered in the context of other methods by Grant and Bixley (2011), Monte Carlo heat-in- place approaches are commonly misleading and difficult to validate. If such an analysis is needed to meet a reviewer's request, the City of Akutan could consider employing a large consultancy that routinely provides such analyses to meet regulatory needs, like GeothermEx or SKM. 28 Akutan Geothermal Resource Assessment Resource Risks The major volcanic hazard posed to a geothermal development on Akutan is ash fall. The modern volcanic complex forms the western half of the island, and future eruptions are unlikely to affect the eastern portions of the island (Ancestral Akutan), including HSBV. Destabilization of the fumarole area, at an elevation of 1150' (350 m; see Fig. 1), may generate debris flows, and such deposits are seen in the valley floor. According to the hazards map of Akutan, it is possible that the entire HSBV could be inundated by cohesive lahars associated with small-scale slope failure(s), but not likely. Another possible but unlikely hazard is a pyroclastic flow near the fumarole field (Waythomas et. al., 1998). Re-injection beneath the surface is the most environmentally responsible means of disposing of the produced fluids. Re-injection also supports reservoir pressure. Normally the fluids would be injected back into the reservoir because this is where adequate permeability exists. Because of the possibility that HSBV is fault-controlled, reinjecting the fluids into the shallow aquifer incurs a high risk of pre- mature thermal breakthrough to the producing wells. This risk can be investigated through pressure- interference and possibly tracer testing as additional delineation wells are drilled. Calcite scaling in the production wells and silica scaling of the production pipeline system and injection wells are both possibilities for the Akutan system. However, gas levels are likely to be moderate and calcium and silica concentrations are low, suggesting that scaling risks should be low. Silica is unlikely to achieve a significant level of supersaturation should the fluids be produced to a binary power plant. Also, the risks of silica precipitation can be mitigated through pH modification of the produced waters. In addition, the potential for producing acid corrosive fluids at Akutan is very low. The hot springs and discharge waters demonstrate that the reservoir hosts a near neutral chloride reservoir. Further assessment of the risks would require the acquisition of additional well performance data, such as interference testing, and additional geochemical samples from the production and injection zones. Upflow Development Risks Two key questions remain unresolved concerning the deep high temperature ("upflow") resource. The first is the location of the upflow to the system. The second is the volume of the high temperature resource. Resolution of these questions would require additional drilling and possibly the acquisition of additional resistivity data near and to the west of the fumaroles. A reasonable minimum size at a 10% confidence level would be the area covered by the fumaroles and gassy alteration. If this is taken to be roughly 1500 ft2 (0.5 km2) then using the base case numbers for power density of 15 MW/km2, a reasonable minimum for expected capacity of the upflow is 8 MW after Grant and Bixley(2011). The risk of volcanic hazards should be carefully investigated if the wellpad were to be sited near the fumarole field on the flank of Akutan volcano, as that location lies on a possible path of pyroclastic flows from Akutan volcano(Waythomas et al, 1998). Fumarole gas contents are 3.5 to 4 wt. %, which do not present an obstacle to development. A well drilled beneath the fumarolic complex is also at a low risk of encountering acid fluids, because the gas chemistry is indicative of a neutral chloride upflow to the geothermal system. 29 Akutan Geothermal Resource Assessment Outflow Development Risks Other than the general risks mentioned above (injection breakthrough, scaling/corrosion, etc),the most important development risk of the outflow resource discovered by core hole TG-2 is permeability and/or volume limitations. Neither of the coreholes encountered clay alteration characteristic of a well- developed smectite-rich argillic caprock. Perhaps the argillic alteration did not develop because of dense lavas, or higher rank alteration that does not retrograde, or it never became well-developed, or perhaps it was eroded off. Resistivity profiles of the HSBV also suggest only a very thin conventional clay has formed over the outflow system, close to the hot springs (Kolker et al., 2009). The rocks in general • appear to be only weakly altered. This implies that HSBV does not host a substantial volume of hot fluid, .� making it a risky development target. Mineralogical studies of TG-2 core rocks suggest that secondary mineralization of permeable fractures has "sealed"the outflow area, restricting flow. Analysis of the temperature profiles and flow behavior of TG-2 suggests that the produced fluid of 359 °F (182 °C) was "pulled" into the system from elsewhere. The subsurface source of the 359 °F (182 °C) fluid is unknown and therefore targeting this resource is highly risky. Additionally, there is a high risk that exploitation of the shallow reservoir could result in rapid enthalpy declines during exploitation. The risk arises from any of the following: recharge of the reservoir by sea water; cold meteoric water influx from near surface aquifers; and breakthrough from injection wells. Groundwater influx probably poses the most significant risk. There are also a large number of connection points between the shallow thermal aquifer and the surface along the outflow path. Any pressure decline as a result of exploitation would likely allow these colder waters to descend into the reservoir and cool the production wells. Conclusions The Akutan geothermal resource can be divided into an upflow zone and one or more outflow zones. Studies of alteration minerals in the core suggest that the outflow resource discovered by TG-2 is likely to have significant permeability limitations (Stelling and Kent, 2011).The outflow resource of 359°F (182 °C) discovered by slimhole exploratory drilling in 2010 appears to have migrated from a more distal source and may not be commercially developable. A temperature reversal at the bottom of the stabilized TG-2 profile reduces the possibility that a hotter or more voluminous reservoir would be encountered by drilling deeper at that location. These conclusions indicate that earlier estimates of production capacity of the outflow resource discovered by slimholes are inaccurate, because the flow assumptions for this estimate appear to have been overly optimistic. The hottest modern zone in the TG-2 core is at 585-590' (178-180 m), with a static measured temperature of 338 °F (165 °C). The occurrence of wairakite, epidote and prehnite suggest that this zone was permeable during the earlier higher temperature alteration event. The outflow zone penetrated by the exploratory slimholes shows evidence of "self-sealing" through mineralization of primary and secondary permeability channels. The chlorite- and zeolite-dominated hydrothermal mineralogy of wells TG-2 and TG-4 indicate that a lower temperature alteration assemblage has been overprinted on a higher temperature assemblage. The higher temperature alteration assemblage contains illite, epidote, prehnite, and adularia. The mixed layer clays, illite-smectite and chlorite- 30 Akutan Geothermal Resource Assessment smectite, and zeolites are part of the lower temperature retrograde assemblage corresponding to temperatures of 300 — 430 °F (150-220 °C). The overprinting observations can be explained by a vertically-limited outflow system in a waning phase after attaining higher temperatures, which suggests that a deeper well drilled at or near the location of TG-2 is not likely to encounter the hotter fluids predicted by chemical geothermometry. Since those fluids appear to be flowing laterally along the water table towards Hot Springs Bay, the source fluids are probably westward up the valley towards the fumaroles and/or southwest to the valley junction and then northwest (Figs 10 and 12). Future drilling should target the upflow resource as the highest-grade, lowest-risk part of the system. The upflow source fluids are likely to be within the range of 428-572 °F (220-300°C), and are chemically benign. The estimated output capacity of the upflow target is 15-100 MW by analog analysis, with a minimum output of 8 MW based on pessimistic volume considerations. If developing the upflow resource is not possible,the hottest part of the lower-grade outflow zone could be targeted but with greater risk. Recommendations The unresolved resource properties and risks can only be addressed by additional characterization of the resource through drilling. An evaluation of the access, drilling and financial issues involved in targeting a well on the upflow resource below the fumarole should be top prioirity at this time. Future well(s) should be directed west beneath the fumaroles or north to a postulated upflow beneath a local resistivity high. The well should attain a minimum depth of 4500' (1350m) to insure that it penetrates through the reservoir top, although a target depth of 6000' (1800m) would be preferable in order to better establish reservoir thickness. As evaluation of the resource potential continues, obtaining samples of separated steam and water from the production wells will be valuable for further assessing the geochemical risks related to scaling and cold water influx. Pressure-interference and possibly tracer testing will need to be conducted as additional wells are drilled. The risks associated with drilling the upflow target could be mitigated by additional exploration work. One focus of additional exploration work could be the identification of controlling structures (likely faults). Since hot fluids are constantly plugging up the "plumbing" channels by depositing minerals in open fractures, large-scale activity on faults is required to keep the system permeable.These faults must exist, but none have been conclusively identified in HSBV or near the fumaroles. Hence, mapping large- scale active structures controlling permeability in the Akutan geothermal field could reduce well targeting risks. Aerial photography survey planned for summer 2011 may provide useful data. Additional studies (LIDAR, seismic, or other geophysical methods) could supplement this investigation after the initial review of the aerial photography. Another exploration activity that could mitigate the upflow target drilling risk is extending coverage of the MT survey further to the north and west of HSBV. This could be done with very limited additional stations (possibly 10-20) with or without a helicopter, limited to the area in the direct vicinity of the fumaroles. However,this additional data may not have a significant effect on the project risk assessment of the outflow, especially along the north rim of the outflow. Because it is likely to be relatively expensive and prone to severe wind noise,this activity is not top priority at this time. 31 Akutan Geothermal Resource Assessment If the shallow outflow is deemed to be more suitable for geothermal development, an important risk mitigation measure would be analog studies of more shallow outflows that have been developed for power generation and/or space heating. Analog studies of similar geologic environments in Iceland could be particularly useful for assessing risks associated with cold water influx and injection breakthrough. Additionally, several low-cost additional studies could help characterize the outflow resource.These include: (1) Fluid inclusion analysis of hydrothermal minerals in deposited in fractures in core rocks; (2)Analysis of the fracture orientation within well cores; (3) Detailed clay analysis identifying the percentages of illite in illite-smectite and chlorite-smectite. As with the upflow target, pressure- interference and possibly tracer testing should be conducted as additional wells are drilled. References and Bibliography Black, Robert F., 1975. Late quaternary geomorphic processes: Effects on the ancient Aleuts of Umnak Island in the Aleutians.Arctic,v.28,p. 159-169 Coombs, D.S., Ellis,A.J., Fyfe,W.S.,and Taylor,A.M.(1959)The zeolite facies,with comments on the interpretation of hydrothermal syntheses. Geoch.Cosmoch.Acta 17,53-107. Cumming, W., 2009. Geothermal resource conceptual models using surface exploration data. Proceedings, 34th Workshop on Geothermal Reservoir Engineering,Stanford University,Stanford,CA. Cumming, W. and Mackie, R., 2010. Resistivity Imaging of Geothermal Resources Using 1D, 2D and 3D MT Inversion and TDEM Static Shift Correction Illustrated by a Glass Mountain Case History. Proceedings, World Geothermal Congress 2010. Garg and Combs, 2010. A Reexamination of USGS Volumetric "Heat in Place" Method. Proceedings, Thirty-Sixth Workshop on Geothermal Reservoir Engineering,Stanford University,Stanford,California,SGP-TR-191,5p. Glassley,W.,2008.Geothermal Energy: Renewable Energy and the Environment.CRC Press,290p, Giggenbach, W., 1991. Chemical Techniques in Geothermal Exploration. In: The Application of Geochemistry in Geothermal Reservoir Development, F. D'Amore Ed. 1991 UNITAR/UNDP Guidebook. Grant, M.A.,and P.F. Bixley,2011.Geothermal Reservoir Engineering,2nd Edition. El Sevier Press,378 p. Information Insights, 2010.Akutan Geothermal Energy Demand and Stakeholder Assessment. Unpublished report to the City of Akutan and the Alaska Energy Authority,34p. Kolker, A., 2008. Geologic Setting of the Central Alaskan Hot Springs Belt: Implications for Geothermal Resource Capacity and Sustainable Energy Production. Ph.D. Dissertation, University of Alaska Fairbanks,203p. Available Online at: http://www.uaf.edu/rap/students/Alumni/Kolker-dissertation-2008.pdf Kolker,A.,and R. Mann,2009. Heating Up The Economy With Geothermal Energy:A Multi-Component Sustainable Development Project at Akutan,Alaska.Geothermal Resource Council Transactions No.33, 11p. Kolker,A., P.Stelling, B. Cumming,A. Prakash, and C. Kleinholt, 2009.Akutan Geothermal Project: Report on 2009 Exploration Activities. Unpublished report to the City of Akutan and the Alaska Energy Authority,37p. Kolker,A., B. Cumming, and P. Stelling, 2010. Akutan Geothermal Project: Preliminary Technical Feasiblity Report. Unpublished report to the City of Akutan and the Alaska Energy Authority,31p. 32 Akutan Geothermal Resource Assessment Kolker,A., B.Cumming,and P.Stelling,2010. Geothermal Exploration at Akutan,Alaska: Favorable Indications for a High-Enthalpy Hydrothermal Resource Near a Remote Market. Geothermal Resource Council Transactions No. 34, 14p. Kolker, A., A. Bailey, W.T. Howard, 2011. Akutan Geothermal Project: Summary of Findings from the 2010 Exploratory Drilling Program. Unpublished report to the City of Akutan and the Alaska Energy Authority,33p. Lu,Z.,C.Wicks,D. Dzurisin,W.Thatcher,and J. Power,2000.Ground Deformation Associated with the March 1996 Earthquake swarm at Akutan Volcano, Revealed by Satellite Radar Interferometry. Journal of Geophysical Research,v. 105, No. B9,p.21483-21495. Miller,T.P., G. McGimsey, D. Richter,J. Riehle, C. Nye, M. Yount, and J. Dumoulin, 1998. Catalog of the historically active volcanoes of Alaska. USGS Open-file Report 98-582. Motyka, R., and C. Nye, eds., 1988.A geological,geochemical, and geophysical survey of the geothermal resources at Hot Springs Bay Valley, Akutan Island, Alaska. Alaska Division of Geological and Geophysical Surveys (ADGGS), Report of Investigations 88-3. Motyka, R.J., S. Liss, C. Nye, and M. Moorman, 1993. Geothermal Resources of the Aleutian Arc. ADGGS Professional Paper 114. Newhall,C.G.,and D. Dzurisin, 1988. Historical unrest at large calderas of the world. USGS Bulletin 1855. Newendorp, P. and Schuyler,J., 2000. Decision Analysis for Petroleum Exploration,Second Edition. Planning Press, pp.618. Powell, T., and W. Cumming., 2010. Spreadsheets for Water and Geothermal Gas Chemistry. Proceedings of the Thirty-Fifth Workshop on Geothermal Reservoir Engineering,Stanford University,Stanford,California,SGP-TR- 188. Richter, D.H., C.F. Waythomas, R.G. McGimsey, and P.L. Stelling, 1998. Geology of Akutan Island, Alaska. USGS Open-File Report 98-135, 1 sheet, 1:63,360 scale Rohrs, D., 2011."Geochemistry of the Akutan Geothermal Prospect,Alaska." Unpublished report to City of Akutan, 36p. Seki,Y.,Onuki,H.,Okumura, K.,and Takashima, I.(1969b)Zeolite distribution in the Katayama geothermal area, Onikobe,Japan.Jap.J.Geol.Geogr.40,63-79. Simkin, T., and L. Siebert, 1994, Volcanoes of the World, 2nd edition: Geoscience Press in association with the Smithsonian Institution Global Volcanism Program,Tucson AZ,368 p. Symonds, R. B., R. Poreda, W. C. Evans, C. J. Janik, and B. E. Ritchie, 2003. Mantle and crustal sources of carbon, nitrogen,and noble gases in Cascade-Range and Aleutian-Arc volcanic gases. USGS Open-File Report 03-436. Waythomas, C.F, J.A. Power, D.H. Richter, and R.G. McGimsey, 1998. Preliminary Volcano-Hazard Assessment for Akutan Volcano, East-Central Aleutian Islands,Alaska: U.S. Geological Survey Open-File Report OF 98-0360, 36 p., 1 plate,scale unknown. Western Governors' Association Clean and Diversified Energy Initiative Report, 2006. http://www.westgov.org/wga/initiatives/cdeac/Geothermal-ful I.pdf 33 Akutan Geothermal Resource Assessment WesternGeco,2009. Magnetotelluric Survey at Hot Springs Bay Valley,Akutan,Alaska: Final Report—3D Resistivity Inversion Modeling. Unpublished report prepared for the City of Akutan, Alaska, GEOSYSTEM/WesternGeco EM, Milan, Italy,27p. Wood, C.P, 1994. Mineralogy at the magma-hydrothermal system interface in andesite volcanoes, New Zealand. Geology,22,75-78. 34 k14A- STATE OF ALASKA q(141 Z.v to ALASK„JIL AND GAS CONSERVATION COMMISoiON WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other E Abandoned ❑ Suspended lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory 0 • GINJ ❑ WINJ ❑ WAG ❑ WDSPL❑ No.of Completions: _1 Service ❑ Stratigraphic Test ❑ 2.Operator Name: 5.Date Comp.,Susp.,or 12.Permit to Drill Number: City of Akutan Aband.: 8/24/2010 . 210073 / 3.Address: 6.Date Spudded: 13.API Number: 3380 C Street,Suite 205,Anchorage,AK 99503-3952 8/11/2010 • 50-295-20004-00-00 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 'S, 11.45'E,S7,T70S,R112W.SM •1$31 F tzL 8/21/2010 ' South Elbow Well/4 Top of Productive Horizon: 1010 FAL 8.KB(ft above MSL): 123• 15.Field/Pool(s): -rub b 041/4 5..t 5'S,120.6'E,S7,T70S,R112W.SM GL(ft above MSL): 119 • Hot Springs Bay Valley Total Depth: 9.Plug Back Depth(MD+TVD): iJk.��,1L it I( - 4"u ' 5)'S, 1 5'E,S7,T70S,R112W.SM • N/A r� 6, yY14A.( 3 }.c 4b.Location of Well(State Base Plane Coordinates,NAD 27): / y.ly.ly 10.Total Depth(MD+TV 16.Property Designation: <" a Surface: x- 526623.5 •52`' 10 y- 50556''3 6057{{ Zone- 8 . 1500'+1500' Fee Agent Corporation ` TPI: x- 526623.5 y- 50556.3 Zone- 8 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 526623.5 y- 50556.3 Zone- 8 N/A Subsurface Agreements 18.Directional Survey: Yes ❑ No ✓❑Drift surveys while drilling 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) (ft MSL) N/A 21.Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drill/Lateral Top Window MD/TVD: Pressure/Temperature logs run at TD. N/A 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMO CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD LED 6.625 20 K55 0 33 0 33 9.875 Tremie w/13.5#Type 2 Premiu.el./ Ws 4.5 11.2 4130 3 186 3 186 5.5 13.5#Type 2 Premium w/30% 460 664 3.5 8.69 4130 3 596 3 596 3.87 13.5#Type 2 Premium w/30% -91T surf 24.Open to production or injection? Yes E No❑ If Yes,list each 25. TUBING RECORD Foot valve at end of 1.66"tubing-tubing can only be circulated from surface. SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 1.66 1491 0(hung from wellhead) �, y.' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. '`'"'4:1111 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED a . i t i RBDMS SEP 13 2010 27. PRODUCTION TEST Date First Production: N/A Method of Operation(Flowing,gas lift,etc.): Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period - Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate 28. CORE DATA Conventional Core(s)Acquired? Yes ❑Q No❑ Sidewall Cores Acquired? Yes ❑ No❑ If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. FD F .., , - 102.01r'. ,: , . r r �:. "r Iraission Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit original only f.f4-/v 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? 0 Yes ❑ No If yes, list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form, if Permafrost-Top N/A N/A needed,and submit detailed test information per 20 AAC 25.071. Permafrost-Base N/A N/A Performed formation integrity test to 0.625 gradient at 208'. Performed leakoff Alluvium 5'to 57' 5'to 57' at 620'to 1.3 gradient with no leakoff. Well was airlifted at TD and formation Akutan 57' 57' fluid samples were obtained. (mixed volcanics/volcaniclastics) Formation at total depth: 1500' 1500' (mixed volcanics/volcaniclastics) 31. List of Attachments: Mud logs and pressure/temperature logs. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Amanda Kolker Printed Name: Amanda Kolker Title: Akutan Geothermal Project Manager Signature: � ��^ Phone: 971-322-5002 Date: 9/7/2010 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 b: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Temperature ( degF) 0 0 0 0 0 o Ln o Ln LU 0 0 M N N In i I • 1- �' CO It.:. • A M - O ,-.0 La ' N ,. N N E a. `° k� Qyp 4tt E i<ceQ,..! ri co,- a) % / • � Co a 5 le)s, N a 2 y z w P.2 o a o N 7 S 1 1 1 1 ! ILI 1 1 1 1 11111111 1111 1L_11 1 1 1 1 1 1 1 111 1 1 1 1 I I t ( 11 t C 81 I QQI I I I C Ib *0 *0 § v- 0 0 UI O li! O In N (isd ) amssaid !V Temperature ( degF) 0 ion o t g f7 N N 1 1 I i 2 a.. <31 N N 119 = N -/ M W 11 cz m N V.3 a) N a E Oe E X F- r�� H W tiI E N (9 K a) al a Q a) I— m n RS a) c2 a a E co a) I a) a) o a o N co 7 t i I 1 1 i l l1 1 1 1 I I I C 0 p p1 Q 1100 '0 O ill O If) 0 0 1f0 ) 0 o U0 ) 0 0 11) 0 1A (0 (0 10 111 V V CO co N N e- 41- N (isd ) amssaJd N Temperature ( degF) O 0 O O O O Lf) O in O O M N N r In 4 r f.-_r . 2 Q O) t 00 CC 1---- = N •r��� M LL] 1mi Ce Ce p a.7 I— W W M F- a) N m rN' X c V Q N 0.1 a) 111 . . \E a) H I S2 n u) N m o Q. o N C) Q ) 1 i i ! i i i III C O O 0 0 0 0 0 0 0 0 0 0 0 0 0 2 u7 0 LA 0 i[) O It) 0 Lf) 0 T O It) CO CO CO in L() vt d' co CON N r- CO 0sd ) aJnssaJd L Y Q) C N t co I WV 90:IV:8 WV 90:0E:8 WV 90:6T:8 INV 90:80:8 WV 90:LS:L INV 90:9b:L WV 90:SE:L WV 90:VZ:L 4-+ WV 90:ET:L N WV 90:ZO:L •—. 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1:08 93 21 8/24/2010 1:09 92 22 8/24/2010 1:09 91 23 8/24/2010 1:10 89 24 8/24/2010 1:10 88 25 8/24/2010 1:11 87 26 8/24/2010 1:11 87 27 8/24/2010 1:12 86 28 8/24/2010 1:12 86 29 8/24/2010 1:13 85 30 8/24/2010 1:13 84 31 8/24/2010 1:14 84 32 8/24/2010 1:14 84 33 8/24/2010 1:15 83 34 8/24/2010 1:15 83 35 8/24/2010 1:16 82 36 8/24/2010 1:16 82 37 8/24/2010 1:17 82 38 8/24/2010 1:17 82 39 8/24/2010 1:18 84 !1 40 8/24/2010 1:18 84 41 8/24/2010 1:19 85 42 8/24/2010 1:19 84 43 8/24/2010 1:20 85 44 8/24/2010 1:20 85 45 8/24/2010 1:21 84 46 8/24/2010 1:21 83 47 8/24/2010 1:22 83 48 8/24/2010 1:22 83 49 8/24/2010 1:23 83 50 8/24/2010 1:23 83 51 8/24/2010 1:24 83 52 8/24/2010 1:24 82 53 8/24/2010 1:25 82 54 8/24/2010 1:25 82 55 8/24/2010 1:26 82 56 8/24/2010 1:26 80 57 8/24/2010 1:27 79 58 8/24/2010 1:27 79 59 8/24/2010 1:28 79 60 8/24/2010 1:28 79 61 8/24/2010 1:29 79 62 8/24/2010 1:29 78 63 8/24/2010 1:30 78 64 8/24/2010 1:30 78 65 8/24/2010 1:31 77 66 8/24/2010 1:31 75 67 8/24/2010 1:32 75 68 8/24/2010 1:32 74 69 8/24/2010 1:33 73 70 8/24/2010 1:33 73 71 8/24/2010 1:34 73 72 8/24/2010 1:34 73 73 8/24/2010 1:35 73 74 8/24/2010 1:35 72 75 8/24/2010 1:36 72 76 8/24/2010 1:36 72 77 8/24/2010 1:37 72 78 8/24/2010 1:37 72 79 8/24/2010 1:38 71 80 8/24/2010 1:38 71 81 8/24/2010 1:39 71 82 8/24/2010 1:39 71 83 8/24/2010 1:40 70 84 8/24/2010 1:40 70 85 8/24/2010 1:41 70 86 8/24/2010 1:41 70 87 8/24/2010 1:42 70 88 8/24/2010 1:42 70 89 8/24/2010 1:43 68 90 8/24/2010 1:43 68 91 8/24/2010 1:44 68 92 8/24/2010 1:44 68 93 8/24/2010 1:45 68 94 8/24/2010 1:45 68 95 8/24/2010 1:46 67 96 8/24/2010 1:46 67 97 8/24/2010 1:47 66 98 8/24/2010 1:47 66 99 8/24/2010 1:48 66 100 8/24/2010 1:48 66 101 8/24/2010 1:49 66 102 8/24/2010 1:49 66 103 8/24/2010 1:50 65 104 8/24/2010 1:50 65 105 8/24/2010 1:51 65 106 8/24/2010 1:51 65 107 8/24/2010 1:52 64 108 8/24/2010 1:52 64 109 8/24/2010 1:53 64 110 8/24/2010 1:53 64 111 8/24/2010 1:54 64 112 8/24/2010 1:54 64 113 8/24/2010 1:55 63 114 8/24/2010 1:55 63 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O-D j0 a) (0 U .0 a) U �� aTO t a) C O II ma a- 3�o-0o mN cE �_ o .0 a) ° (20y00oa)c r- Q o U -C O a) E m tis `a. o s a)- ' fov ms n c oN a) •= v = ✓, Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-4 Well Name:South Elbow Well Field: Hot Springs Bay Va County:Aleutians East State:AK Country: United States Report No: 1 Report For 09-Aug-10 Operator: City Of Akutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 0 Drilling Days: 24 plan RKB Elevation: 10.00 County: Aleutians East Vertical Depth(ft): 0 Days On Location: 1 Last Casing: Field: Hot Springs Bay Hole Made: 0 Spud Date: 11-Aug-10 Next Casing: 6.625 at 30 Working Interest: Drilling Hrs: 0 Average ROP: 0 Last BOP Test: Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 4 Total: 18 Current Operations: Waiting on daylight. Planned Operations: Continue to move and rig up on wellsite 4. Toolpusher: Dave Griggs Wellsite Supervisors: Dan Darnell Tel No.: 1-907-444-1777 Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 8:00 20:00 12.00 0 MOB Began moving equipment from Wellsite 2 to Wellsite 4. Comments Began moving between wellsites. Cost/AFE Information AFE No AFE Description AFE Amount Daily Mud Well Mud Daily Total Well Total %Spent No AFE Assigned 0 0 0 56,065 56,065 Totals$: 0 0 0 56,065 56,065 Rig Information Equipment Problems: Location Condition: Transport: Safety Information Meetings/Drills Time Description Safety 30 Safety meeting held with both crews First Aid: Medical: Lost Time Accidents: Days Since LTA: 0 0 BOP Test ❑ Crownamatic Check Printed: 19:52 13-Sep-10 RIMBase 5.1.1.177 Page: 1 of 1 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-4 Well Name:South Elbow Well Field: Hot Springs Bay Va County:Aleutians East State:AK Country: United States Report No: 2 Report For 10-Aug-10 Operator: City Of Akutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 0 Drilling Days: 24 plan RKB Elevation: 10.00 County: Aleutians East Vertical Depth(ft): 0 Days On Location: 2 Last Casing: Field: Hot Springs Bay Hole Made: 0 Spud Date: 11-Aug-10 Next Casing: 6.625 at 30 Working Interest: Drilling Hrs: 0 Average ROP: 0 Last BOP Test: Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 4 Total: 18 Current Operations: Waiting on daylight. Planned Operations: Continue to move and rig up on AGP TG-4 location Toolpusher: Dave Griggs Wellsite Supervisors: Dan Darnell Tel No.: 1-907-444-1777 Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 8:00 20:00 12.00 0 MOB Rig Move,Move equipment from AGP TG-2 and rig up on AGP TG-4 location, Comments Continued moving and rigging up. Cost/AFE Information AFE No AFE Description AFE Amount Daily Mud Well Mud Daily Total Well Total %Spent No AFE Assigned 0 0 0 12,465 68,530 Totals$: 0 0 0 12,465 68,530 Rig Information Equipment Problems: Belt on Light Plant Location Condition: Transport: Safety Information Meetings/Drills Time Description Safety 30 Safety meeting held with both crews First Aid: Medical: Lost Time Accidents: Days Since LTA: 1 ❑ BOP Test ❑ Crownamatic Check Weather Information Sky Condition: Cloudy/Rain Visibility: Air Temperature: Bar.Pressure: Wind Speed/Dir: / Wind Gusts: Printed: 19:52 13-Sep-10 RIMBase 5.1.1.177 Page: 1 of 1 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-4 Well Name: South Elbow Well Field: Hot Springs Bay Va County:Aleutians East State:AK Country: United States Report No: 3 Report For 11-Aug-10 Operator: City Of Akutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 38 Drilling Days: 1 actual/24 plan RKB Elevation: 10.00 County: Aleutians East Vertical Depth(ft): 38 Days On Location: 3 Last Casing: Field: Hot Springs Bay Hole Made: 38 Spud Date: 11-Aug-10 Next Casing: 6.625 at 30 Working Interest: Drilling Hrs: 5.5 Average ROP: 6.9 Last BOP Test: Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 4 Total: 18 Current Operations: Continued opening hole 7 1/2"to 9-7/8". Planned Operations: Finish opening hole. Run and cement 6-5/8"casing. Toolpusher: Dave Griggs Wellsite Supervisors: Dan Darnell Tel No.: 1-907-444-1777 Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 8:00 14:30 6.50 0 RIGU Rigged up on South Elbow wellsite and conducted prespud meeting. 14:30 20:00 5.50 38 DRIL Cored 5-1/2"hole f/5't/38'.Circ and POH. 20:00 22:00 2.00 38 OPEN Opened hole from 5-1/2"to 7-1/2" f/5't/38'.Circ and POH. 22:00 0:00 2.00 38 OPEN Opened hole from 7-1/2"to 9-7/8" f/5't/27'. Management Summary Mud pumps packing off due to sand. Cost/AFE Information AFE No AFE Description AFE Amount Daily Mud Well Mud Daily Total Well Total %Spent No AFE Assigned 0 0 0 37,429 105,959 Totals$: 0 0 0 37,429 105,959 Mud Information Gels Temp Density Vis PV YP Filt. Cake pH Solids Oil Water Sand Chloride Calcium 10s 10m 30m In Out 11-Aug-10 22:00 60 Bit/BHA Information Depth This Run R.O.P. Mud Pump No Run Make Model Diam In Dist Hrs Avg Max WOB RPM Torque Wt Flow Press J.Vel P.Drp HHP JIF 1 1 FORD; 5.500 5 33 5.5 6.0 8 70 150 Jets: Out: 38 Grade: Cutter: / Dull: / Wear: Brgs: Gge: Pull: 2 1 B HUGE GT-1 7.500 5 33 2 16.5 150 8 70 150 Jets: 18 18 18 Out: 38 Grade: Cutter 1/1 Dull: NO/NO Wear A Brgs: E Gge: 1 Pull: OTH 3 1 B HUGE GT-1 9.875 5 22 1 22.0 8 70 150 Jets: 18 18 18 Out: 38 Grade: Cutter: 2/2 Dull: NO/NO Wear:A Brgs: E Gge: 1 Pull: OTH Drilling Parameters ROP WOB(lbs) RPM Torque(ft lbs) Flow(gals/min) From To Avg Max Avg Max Avg Max Avg Max Avg Max PSI 0 27 5.0 10.0 150 250 Comments: Cored 5 1/2"pilot hole fallowed by drilling a 7 1/2"hole and then opening the 7 1/2"to 9 7/8"hole f/5'to 27'@00:00 hrs Rig Information Equipment Problems: Location Condition: Transport: Safety Information Meetings/Drills Time Description Safety 30 Prespud Meeting First Aid: Medical: Lost Time Accidents: Days Since LTA: 2 ❑ BOP Test ❑ Crownamatic Check Printed: 19:52 13-Sep-10 RIMBase 5.1.1.177 Page: 1 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-4 Well Name:South Elbow Well Field: Hot Springs Bay Va County:Aleutians East State:AK Country: United States Report No: 3 Report For 11-Aug-10 Weather Information Sky Condition: Rain/Rain/Rain Visibility: Air Temperature: Bar.Pressure: Wind Speed/Dir: / Wind Gusts: Comments: LELS in cellar are checked twice every day Printed: 19:52 13-Sep-10 RIMBase 5.1.1.177 Page:2 of 2 Daily Drilling Report Geothermal Resource Group 1)4°0 Well ID: AGP TG-4 Well Name:South Elbow Well Field: Hot Springs Bay Va County:Aleutians East State:AK Country: United States Report No: 4 Report For 12-Aug-10 Operator: City Of Akutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 38 Drilling Days: 2 actual/24 plan RKB Elevation: 5.00 County: Aleutians East Vertical Depth(ft): 38 Days On Location: 4 Last Casing: 6.625 at 38 Field: Hot Springs Bay Hole Made: 0 Spud Date: 11-Aug-10 Next Casing: 4.500 at 150 Working Interest: Drilling Hrs: 0 Average ROP: 0 Last BOP Test: Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 4 Total: 18 Current Operations: WOC. Installed 6-5/8'riser,3"flow line and fill up line. RIH and tagged TOC @ 34'.Cleaned out cement and cored ahead f/38'@ 06:00 hr's. Planned Operations: Continue to core 5-1/2"hole to casing point. Toolpusher: Dave Griggs Wellsite Supervisors: Dan Darnell Tel No.: 1-907-444-1777 Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 12:00 12.00 38 OPEN Opened hole w/9-7/8"bit f/27't/38'. 12:00 12:30 0.50 38 CIRC Circ and conditioned hole for conductor. 12:30 13:00 0.50 38 TRPO POH&UD rotary tools. 13:00 14:00 1.00 38 CASE Ran 33'of 6-5/8"24#K55 as conductor with bottom of pipe @ 38'. 14:00 15:00 1.00 38 CMTP Pumped 3.4 bbls of 13.5#cement via tremie.Job required 100%excess.CIP @ 14:50 hrs. 15:00 0:00 9.00 38 WOC WOC, Comments Finished opening hole to 9-1/8". Set and cemented 6-5/8"conductor. WOC. Casing Information Type Size Top MD Top ND Bottom MD Bottom ND Hole Section Avg OH Diam LOT FULL 6.625 5 5 38 38 COND 10.000 Cost/AFE Information AFE No AFE Description AFE Amount Daily Mud Well Mud Daily Total Well Total %Spent No AFE Assigned 0 0 0 35,105 141,064 Totals$: 0 0 0 35,105 141,064 Mud Information Gels Temp Density Vis PV YP Filt. Cake pH Solids Oil Water Sand Chloride Calcium 10s 10m 30m In Out 12-Aug-10 04:00 8.40 55 65 65 Bit/BHA Information Depth This Run R.O.P. Mud Pump No Run Make Model Diam In Dist Hrs Avg Max WOB RPM Torque Wt Flow Press J.Vel P.Drp HHP JIF 3 1 B HUGF GT-1 9.875 5 33 13 2.5 60 8 70 150 30 7 0 9 Jets: 18 18 18 Out: 38 Grade: Cutter: 2/2 Dull: NO/NO Wear:A Brgs: E Gge: 1 Pull: OTH Drilling Parameters ROP WOB(lbs) RPM Torque(ft lbs) Flow(gals/min) From To Avg Max Avg Max Avg Max Avg Max Avg Max PSI 27 38 2.0 5.0 60 65 70 70 150 Annular Velocity: Drill Collars: 576.2 Drill Pipe: 576.2 Comments: Opened hole f/7 1/2"to 9 7/8"f/27'to 38' Rig Information Equipment Problems: Need fan belt on light Location Condition: good Transport: poor Printed: 19:52 13-Sep-10 RIMBase 5.1.1.177 Page: 1 of 2 Daily Drilling Report Geothermal Resource Group 00 t7 ,, Well ID: AGP TG-4 Well Name: South Elbow Well Field: Hot Springs Bay Va County:Aleutians East State: AK Country: United States Report No: 4 Report For 12-Aug-10 Inventory Bulk Used This Received This Bulk Used This Received This Material Report Period Report Period Inventory Material Report Period Report Period Inventory BARITE 156 44 GEL 360 24 CaC 58 42 AQUA PAC 0 20 CEMENT 91 11 POLY VIS 31 5 TORKEASE 0 5 EZ-MUD 26 14 SODA ASH 2 98 DEFOAM14 0 5 DESCO CF 0 5 ZINC 0 1 CAUSTIC 0 6 Safety Information Meetings/Drills Time Description Safety 30 Safety meeting held with both crews First Aid: Medical: Lost Time Accidents: Days Since LTA: 3 ❑ BOP Test ❑ Crownamatic Check Weather Information Sky Condition: Rain/wind Visibility: Air Temperature: Bar.Pressure: Wind Speed/Dir: / Wind Gusts: Comments: LELS in cellar are checked twice every day Printed: 19:52 13-Sep-10 RIMBase 5.1.1.177 Page:2 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-4 Well Name: South Elbow Well Field: Hot Springs Bay Va County:Aleutians East State:AK Country: United States Report No: 5 Report For 13-Aug-10 Operator: City Of Akutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 168 Drilling Days: 3 actual/24 plan RKB Elevation: 5.00 County: Aleutians East Vertical Depth(ft): 168 Days On Location: 5 Last Casing: 6.625 at 38 Field: Hot Springs Bay Hole Made: 130 Spud Date: 11-Aug-10 Next Casing: 4.500 at 150 Working Interest: Drilling Hrs: 21.0 Average ROP: 6.2 Last BOP Test: Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 4 Total: 18 Current Operations: Cored 5-1/2"hole w/PQ rods f/168't/188'. Began losing 5 bbls @ 172'.Circulated until 06:00-pulled from sump. Prepare to set LC plug. Planned Operations: POH to remove bit and core barrel.RIH open ended and set 30'cmt LC plug @ 143'. Toolpusher: Dave Griggs Wellsite Supervisors: Dan Darnell Tel No.: 1-907-444-1777 Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 2:00 2.00 38 WOC WOC 2:00 21:30 19.50 157 DRIL Cored 5-1/2"hole f/38't/157'. Began losing 5 bbls/hr @ 143'. 21:30 22:30 1.00 157 CIRC Circ and checked for loss @ 157'.No loss. 22:30 0:00 1.50 168 DRIL Cored 5-1/2"hole f/157't/168'w/full returns. Comments WOC for conductor.Cored 5-1/2"hole f/38't/168'. Began losing 5 BPH at 143'. Casing Information Type Size Top MD Top TVD Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.625 5 5 38 38 COND 10.000 Cost/AFE Information AFE No AFE Description AFE Amount Daily Mud Well Mud Daily Total Well Total %Spent No AFE Assigned 0 0 0 39,048 180,112 Totals$: 0 0 0 39,048 180,112 Mud Information Gels Temp Density Vis PV YP Filt. Cake pH Solids Oil Water Sand Chloride Calcium 10s 10m 30m In Out 13-Aug-10 20:00 8.40 42 0 51 51 Bit/BHA Information Depth This Run R.O.P. Mud Pump No Run Make Model Diam In Dist Hrs Avg Max WOB RPM Torque Wt Flow Press J.Vel P.Drp HHP JIF 1 2 FORDII 5.500 33 130 22 5.9 12.0 0 1200 8 50 175 Jets: Out: 188 Grade: Cutter: / Dull: / Wear: Brgs: Gge: Pull: Drilling Parameters ROP WOB(lbs) RPM Torque(ft lbs) Flow(gals/min) From To Avg Max Avg Max Avg Max Avg Max Avg Max PSI 38 168 10.0 12.0 800 1200 35 50 175 Comments: Core 5 1/2"hole w/PQ rods,Core F/38'to 168'; Survey Information Survey Meas. Vertical Coordinates Type Depth Inc. Azimuth TVD Closure Section N-S E-W D.L.S. TOTCO 103.0 2.00 Rig Information Equipment Problems: Fixed light plant Location Condition: WET(good) Transport: Poor Printed: 19:52 13-Sep-10 R/MBase 5.1.1.177 Page: 1 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-4 Well Name:South Elbow Well Field: Hot Springs Bay V8 County:Aleutians East State:AK Country: United States Report No: 5 Report For 13-Aug-10 Inventory Bulk Used This Received This Bulk Used This Received This Material Report Period Report Period Inventory Material Report Period Report Period Inventory DEFOAMI4 5 DESCO CF 5 ZINC 1 CaC 42 AQUA PAC 20 CEMENT 11 CAUSTIC 6 BARITE 44 GEL 4 20 POLY VIS 2 4 TORKEASE 5 EZ-MUD 14 SODA ASH 98 Safety Information Meetings/Drills Time Description Safety 30 Safety meeting held with both crews First Aid: Medical: Lost Time Accidents: Days Since LTA: 4 ❑ BOP Test Crownamatic Check Weather Information Sky Condition: Rain/Rain/Rain Visibility: Air Temperature: 39.0 degF Bar.Pressure: Wind Speed/Dir: 35/N Wind Gusts: 72 Comments: LELS in cellar are checked twice every day,We are getting alot of rain,Trying to keep the sump down, Printed: 19:52 13-Sep-10 RIMBase 5.1.1.177 Page:2 of 2 L Daily Drilling Report Geothermal Resource Group Well ID:AGP TG-4 Well Name:South Elbow Well Field: Hot Springs Bay Va County:Aleutians East State:AK Country: United States Report No: 6 Report For 14-Aug-10 Operator: City Of Akutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 188 Drilling Days: 4 actual/24 plan RKB Elevation: 5.00 County: Aleutians East Vertical Depth(ft): 188 Days On Location: 6 Last Casing: 6.625 at 38 Field: Hot Springs Bay Hole Made: 20 Spud Date: 11-Aug-10 Next Casing: 4.500 at 150 Working Interest: Drilling Hrs: 2.0 Average ROP: 10.0 Last BOP Test: Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 4 Total: 18 Current Operations: Circulated and conditioned hole for casing POH.RIH with HWT(4.5")casing-float collar between first and second joint, casing shoe at 176'. Circulated casing with no loss. Planned Operations: Cement HWT casing. Install wellhead and nipple up BOPE. Toolpusher: Dave Griggs Wellsite Supervisors: Dan Darnell Tel No.: 1-907-444-1777 Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 2:00 2.00 188 DRIL Cored 5-1/2"hole f/168't/188'w/7-10 bph loss. • 2:00 8:00 6.00 188 CIRC Circulated and pumped sump down. 8:00 9:00 1.00 188 TRPO POH&UD bit&core barrel. 9:00 9:30 0.50 188 TRPI RIH OEDP to 140'. 9:30 10:00 0.50 188 CMTPL Rig up cementing equipment. 10:00 10:30 0.50 188 CMTPL Mixed 1 bbl of 13.5#premium cement as lost circulation plug and spotted at 140'. CIP @ 10:30 hrs. 10:30 18:00 7.50 188 WOC WOC. Made up tools while waiting. 18:00 19:00 1.00 188 TRPI RIH&Tag TOC @ 120'. 19:00 22:30 3.50 188 CMTD Cleaned out cement f/120't/172'. Fell out of cement at 172'. Ran in hole to 188'. 22:30 0:00 1.50 188 CIRC Circulated and conditioned hole with full returns. Comments Cored 5-1/2"hole f/168't/188'with 5-7 bph losses. Set 1 bbl lost circulation plug and waited on cement. Cleaned out cement f/120'and circulated hole with no loss. Casing Information Type Size Top MD Top TVD Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.625 5 5 38 38 COND 10.000 Cost/AFE Information AFE No AFE Description AFE Amount Daily Mud Well Mud Daily Total Well Total %Spent No AFE Assigned 0 0 0 36,034 216,146 Totals$: 0 0 0 36,034 216,146 Mud Information Gels Temp Density Vis PV YP Filt. Cake pH Solids Oil Water Sand Chloride Calcium 10s 10m 30m In Out 14-Aug-10 23:00 Sample from Mud Pits 8.40 44 9 72 75 Bit/BHA Information Depth This Run R.O.P. Mud Pump No Run Make Model Diam In Dist Hrs Avg Max WOB RPM Torque Wt Flow Press J.Vel P.Drp HHP JIF 1 2 FORDV 5.500 33 150 24 6.2 9 45 150 Jets: Out: 188 Grade: Cutter: / Dull: / Wear: Brgs: Gge: Pull: Drilling Parameters ROP WOB(lbs) RPM Torque(ft lbs) Flow(gals/min) From To Avg Max Avg Max Avg Max Avg Max Avg Max PSI 168 188 10.0 10.0 800 1100 45 45 120 Annular Velocity: Drill Collars: 404.5 Drill Pipe: 404.5 Comments: Cored 5-1/2"hole with partial losses. Printed: 19:52 13-Sep-10 RIMBase 5.1.1.177 Page: 1 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-4 Well Name:South Elbow Well 1 Field: Hot Springs Bay Va County:Aleutians East State:AK Country: United States Report No: 6 Report For 14-Aug-10 Rig Information Equipment Problems: None Location Condition: Wet,muddy. Transport: poor Inventory Bulk Used This Received This Bulk Used This Received This Material Report Period Report Period Inventory Material Report Period Report Period Inventory POLY VIS 0.25 3.75 TORKEASE 5 EZ-MUD 14 SODA ASH 98 DEFOAM14 5 DESCO CF 5 ZINC 1 CAUSTIC 0.25 5.75 BARITE 44 GEL 4 16 CaC 42 AQUA PAC 1 19 CEMENT 7 4 Safety Information Meetings/Drills Time Description Safety 30 Crews held pre-tour safety meetings. First Aid: Medical: Lost Time Accidents: Days Since LTA: 5 BOP Test ❑ Crownamatic Check Weather Information Sky Condition: Cloudy Visibility: Air Temperature: 44.0 degF Bar.Pressure: Wind Speed/Dir: / Wind Gusts: Comments: LELS in cellar are checked twice every day Printed: 19:52 13-Sep-10 RIMBase 5.1.1.177 Page:2 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-4 Well Name:South Elbow Well Field: Hot Springs Bay V8 County:Aleutians East State:AK Country: United States Report No: 7 Report For 15-Aug-10 Operator: City Of Akutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 188 Drilling Days: 5 actual/24 plan RKB Elevation: 5.00 County: Aleutians East Vertical Depth(ft): 188 Days On Location: 7 Last Casing: 4.5 at 186,Test to Field: Hot Springs Bay Hole Made: 0 Spud Date: 11-Aug-10 Next Casing: 3.500 at 600 Working Interest: Drilling Hrs: 0 Average ROP: 0 Last BOP Test: Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 4 Total: 18 Current Operations: Nippled up BOPE,function testing @ 06:00 hr's. Planned Operations: Test BOPE.Make up HQ 3.87"bit and core barrel and run in hole to the TOC.Circ and test csg.Clean out csg and drill 20' of new hole.Perform formation integrity test to.625 psi gradient and drill ahead t/600'. Toolpusher: Dave Griggs Wellsite Supervisors: Dan Darnell Tel No.: 1-907-444-1777 Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 3:00 3.00 188 CIRC Circ and conditioned hole @ 176'. 3:00 4:00 1.00 188 TRPO POH and L/D core barrel and bit. 4:00 6:00 2.00 188 CASE Ran 18 joints/186'of 4-1/2"11.2#4130 HWT casing with float collar between first and second jt. Bakerlocked each joint. Casing shoe at 186'. 6:00 11:30 5.50 188 CIRC Circulated casing and conditioned for cement. 11:30 13:00 1.50 188 WOE Waited for cement to be unloaded at the dock and heli over. X 13:00 14:30 1.50 188 CMTP Mixed and displaced 4.0 bbls of 13.5#premium cement with 30%silica flour,using 100%excess.Good cement returns to surface.Bumped plug with 500 psi. CIP @ 14:30 hrs. 14:30 22:30 8.00 188 WOC WOC. Removed riser. 22:30 0:00 1.50 188 OTHER Slacked off and layed down landing joint. Installed weld ring and began nippling up well head.TOC was 1 ft down from surface. Comments Circulated and conditioned hole. Ran 186'of 4.5"11.2#HWT 4130 casing with shoe at 186'. Cemented casing with good cement to surface. WOC. Layed out riser and began nippling up wellhead and BOPE. Casing Information Type Size Top MD Top TVD Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.625 5 5 38 38 COND 10.000 FULL 4.500 5 5 186 186 SURF 5.500 832.00 CostJAFE Information AFE No AFE Description AFE Amount Daily Mud Well Mud Daily Total Well Total %o Spent No AFE Assigned 0 0 0 43,224 259,370 Totals$: 0 0 0 43,224 259,370 Mud Information % Gels Temp Density Vis PV YP Filt. Cake pH Solids Oil Water Sand Chloride Calcium 10s 10m 30m In Out 15-Aug-10 22:00 8.40 42 Bit/BHA Information Depth This Run R.O.P. Mud Pump No Run Make Model Diam In Dist Hrs Avg Max WOB RPM Torque Wt Flow Press J.Vel P.Drp HHP JIF 1 2 FORDIF 5.500 33 150 24 Jets: Out: 188 Grade: Cutter: / Dull: / Wear: Brgs: Gge: Pull: Survey Information Survey Meas. Vertical Coordinates Type Depth Inc. Azimuth TVD Closure Section N-S E-W D.L.S. TOTCO 208.0 0.75 Rig Information Equipment Problems: None Location Condition: Wet,muddy. Transport: poor Printed: 19.52 13-Sep-10 RIMBase 5.1.1.177 Page:1 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-4 Well Name:South Elbow Well k'4444 Field: Hot Springs Bay Va County:Aleutians East State:AK Country: United States Report No: 7 Report For 15-Aug-10 Inventory Bulk Used This Received This Bulk Used This Received This Material Report Period Report Period Inventory Material Report Period Report Period Inventory DEFOAM14 5 EZ-MUD 14 SODA ASH 98 GEL 16 CaC 42 AQUA PAC 19 CEMENT 4 BARITE 44 POLY VIS 3.75 TORKEASE 5 DESCO CF 5 ZINC 1 CAUSTIC 5.75 Safety Information Meetings/Drills Time Description Safety 30 Crews held pre-tour safety meeting First Aid: Medical: Lost Time Accidents: Days Since LTA: 6 ❑ BOP Test Crownamatic Check Weather Information Sky Condition: Rain/Rain/and more Rain Visibility: Air Temperature: Bar. Pressure: Wind Speed/Dir: / Wind Gusts: Comments: LELS in cellar are checked twice every day Printed: 19:52 13-Sep-10 RIMBase 5.1.1.177 Page:2 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-4 Well Name:South Elbow Well Field: Hot Springs Bay Va County:Aleutians East State:AK Country: United States Report No: 8 Report For 16-Aug-10 Operator: City Of Akutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 301 Drilling Days: 6 actual/24 plan RKB Elevation: 5.00 County: Aleutians East Vertical Depth(ft): 301 Days On Location: 8 Last Casing: 4.5 at 186,Test to Field: Hot Springs Bay Hole Made: 113 Spud Date: 11-Aug-10 Next Casing: 3.500 at 600 Working Interest: Drilling Hrs: 6.5 Average ROP: 17.4 Last BOP Test: 16-Aug-10 Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 4 Total: 18 Current Operations: Cored 3.780"hole f/301'to 410',flow line temp 101 deg F @ 06:00 hr's Planned Operations: Continue to Core and Survey Toolpusher: Dave Griggs Wellsite Supervisors: Dan Darnell Tel No.: 1-907-444-1777 Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 8:00 8.00 188 BOPNU Nipple up BOPE and function test. 8:00 11:00 3.00 188 BOPT Test BOPE and valve's.Low-200, High-750,Test Good _"� 11:00 11:30 0.50 188 TRPI Make up 3.780 bit and core barrel,Pick up HQ rods and RIH,Tagged TOC @ 166' 11:30 12:00 0.50 188 SURV Run temp survey @ 166'MRT 180 deg F • 12:00 15:30 3.50 188 CMTD Clean out cement and wiper plug to the float collar @ 176',continue cleaning out cement f/176'to 188' 15:30 17:30 2.00 208 DRIL Core 3.780 hole f/188'to 208' 17:30 18:00 0.50 208 CIRC Circ hole clean @ 208'and pull up in shoe @ 186' 18:00 19:00 1.00 208 FIT Perform FIT to 12 ppg,Pumped a total of 3 gals @ 1.5 gal a min to 40 psi,Held for 15 min,(test good) 19:00 19:30 0.50 208 SURV Run survey @ 208',-.75 deg,MRT 85 deg F 19:30 0:00 4.50 301 DRIL Core 3.780"hole f/208'to 301'flow line temp 95 deg F Casing Information Type Size Top MD Top ND Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.625 5 5 38 38 COND 10.000 FULL 4.500 5 5 186 186 SURF 5.500 832.00 Cost/AFE Information AFE No AFE Description AFE Amount Daily Mud Well Mud Daily Total Well Total %Spent No AFE Assigned 0 0 0 40,047 299,417 Totals$: 0 0 0 40,047 299,417 Mud Information % Gels Temp Density Vis PV YP Filt. Cake pH Solids Oil Water Sand Chloride Calcium 10s 10m 30m In Out 16-Aug-10 22:00 8.40 44 8 0 52 95 Bit/BHA Information Depth This Run R.O.P. Mud Pump No Run Make Model Diam In Dist Hrs Avg Max WOB RPM Torque Wt Flow Press J.Vel P.Drp HHP JIF 4 1 ADT 8DM 3.780 188 113 6.5 17.4 22.0 1200 8 45 200 Jets: Out: 510 Grade: Cutter: / Dull: / Wear: Brgs: Gge: Pull: Drilling Parameters ROP WOB(lbs) RPM Torque(ft lbs) Flow(gals/min) From To Avg Max Avg Max Avg Max Avg Max Avg Max PSI 188 301 10.0 20.0 1000 1200 35 45 200 Annular Velocity: Drill Collars: 404.0 Drill Pipe: 404.0 Comments: Cored 3.780"hole f/208'to 301'w/full return's Survey Information Survey Meas. Vertical Coordinates Type Depth Inc. Azimuth ND Closure Section N-S E-W D.L.S. TOTCO 301.0 2.50 TOTCO 403.0 2.50 Printed: 19:52 13-Sep-10 RIMBase 5.1.1.177 Page: 1 oft Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-4 Well Name: South Elbow Well Field: Hot Springs Bay V2 County: Aleutians East State:AK Country: United States Report No: 8 Report For 16-Aug-10 Rig Information Equipment Problems: None Location Condition: Wet,muddy. Transport: poor Inventory Bulk Used This Received This Bulk Used This Received This Material Report Period Report Period Inventory Material Report Period Report Period Inventory EZ-MUD 14 SODA ASH 98 DEFOAM14 5 DESCO CF 5 ZINC 1 CAUSTIC 5.75 BARITE 44 GEL 16 CaC 42 AQUA PAC 19 CEMENT 4 POLY VIS 1 2.75 TORKEASE 0.5 4.5 Safety Information Meetings/Drills Time Description Safety 30 Crews held pre-tour safety meeting First Aid: Medical: Lost Time Accidents: Days Since LTA: 7 BOP Test Crownamatic Check Weather Information Sky Condition: Cloudy/Rain Visibility: 3 Air Temperature: 46.0 degF Bar.Pressure: Wind Speed/Dir: / Wind Gusts: 35 Comments: LELS in cellar are checked twice every day Printed: 19:52 13-Sep-10 RIMBase 5.1.1.177 Page:2 of 2 Daily Drilling Report Geothermal Resource Group q..0 Well ID: AGP TG-4 Well Name:South Elbow Well Field: Hot Springs Bay Va County:Aleutians East State:AK Country: United States Report No: 9 Report For 17-Aug-10 Operator: City Of Akutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 547 Drilling Days: 7 actual/24 plan RKB Elevation: 5.00 County: Aleutians East Vertical Depth(ft): 547 Days On Location: 9 Last Casing: 4.5 at 186,Test to Field: Hot Springs Bay Hole Made: 246 Spud Date: 11-Aug-10 Next Casing: 3.500 at 600 Working Interest: Drilling Hrs: 16.25 Average ROP: 15.1 Last BOP Test: 16-Aug-10 Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 4 Total: 18 Current Operations: Cored 3.78"hole f/547't/600'.Circ and survey @ 600'. POH&L/D HQ rods.Made up 3-1/2"HQ parallel wall csg with float collar between first and second joint. Running casing at @ 06:00 hrs. Planned Operations: Run csg and cement.WOC. Toolpusher: Dave Griggs Welisite Supervisors: Dan Darnell Tel No.: 1-907-444-1777 Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 11:30 11.50 503 DRIL Cored 3.78"hole f/301't/503'with full returns. 11:30 12:30 1.00 503 SURV Survey @ 503'2 deg 12:30 13:30 1.00 510 DRIL Cored 3.78"hole f/503't/510'with full returns. 13:30 15:30 2.00 510 TRPO POH to change bit. X 15:30 17:00 1.50 510 TRPI M/U bit#5 and RIH to 510'. X 17:00 19:00 2.00 527 DRIL Cored 3.78"hole f/510't/527'with full returns. Core barrel became stuck. 19:00 20:30 1.50 527 TRPO POH and recovered core. Repaired inner barrel. X 20:30 21:45 1.25 527 TRPI RIH to 527'. X 21:45 22:15 0.50 527 CIRC Circ and cooled well @ 527'. 22:15 0:00 1.75 547 DRIL Cored 3.78"hole f/527'11547'with full returns. Comments Cored 3.78"hole f/301't/503'.Tripped for bit. Cored 3.78"hole f/503'11510'. Tripped to retrieve stuck inner barrel. Cored 3.78"hole f/52711547'. Casing Information Type Size Top MD Top TVD Bottom MD Bottom ND Hole Section Avg OH Diam LOT FULL 6.625 5 5 38 38 COND 10.000 FULL 4.500 5 5 186 186 SURF 5.500 832.00 Cost/AFE Information AFE No AFE Description AFE Amount Daily Mud Well Mud Daily Total Well Total %Spent No AFE Assigned 0 0 0 43,546 342,962 Totals$: 0 0 0 43,546 342,962 Mud Information Gels Temp Density Vis PV YP Filt. Cake pH Solids Oil Water Sand Chloride Calcium 10s 10m 30m In Out 17-Aug-10 22:00 8.40 44 76 101 Bit/BHA Information Depth This Run R.O.P. Mud Pump No Run Make Model Diam In Dist Hrs Avg Max WOB RPM Torque Wt Flow Press J.Vel P.Drp HHP JIF 4 1 ADT 8DM 3.780 188 313 19 16.5 22.0 1200 8 45 210 Jets: Out: 510 Grade: Cutter: / Dull. / Wear: Brgs: Gge: Pull: 5 1 FORDIF Volcan 3.780 510 37 4 9.2 15.0 1200 8 45 210 Jets: Out: 600 Grade: Cutter: / Dull: / Wear: Brgs: Gge: Pull: Drilling Parameters ROP WOB(lbs) RPM Torque(ft lbs) Flow(gals/min) From To Avg Max Avg Max Avg Max Avg Max Avg Max PSI 301 547 10.0 20.0 1000 1200 35 45 210 Annular Velocity: Drill Collars: 404.0 Drill Pipe: 404.0 Comments: Core 3.780"hole f/301'to 547' Printed: 19:52 13-Sep-10 RIMBase 5.1.1.177 Page: 1 of 2 Daily Drilling Report Geothermal,Resource Group Well ID: AGP TG-4 Well Name: South Elbow Well Field: Hot Springs Bay Va County:Aleutians East State: AK Country: United States Report No: 9 Report For 17-Aug-10 Survey Information Survey Meas. Vertical Coordinates Type Depth Inc. Azimuth TVD Closure Section N-S E-W D.L.S. TOTCO 503.0 2.00 Rig Information Equipment Problems: None Location Condition: Wet,muddy. Transport: poor Inventory Bulk Used This Received This Bulk Used This Received This Material Report Period Report Period Inventory Material Report Period Report Period Inventory DEFOAM14 5 DESCO CF 5 ZINC 1 CAUSTIC 5.75 BARITE 44 GEL 16 CaC 42 AQUA PAC 19 CEMENT 4 POLY VIS 1 1.75 TORKEASE 4.5 EZ-MUD 14 SODA ASH 98 Safety Information Meetings/Drills Time Description Satety 30 Crews held pre-tour safety meeting First Aid: Medical: Lost Time Accidents: Days Since LTA: 8 111 BOP Test Crownamatic Check Weather Information Sky Condition: Cloudy Visibility: Air Temperature: Bar.Pressure: Wind Speed/Dir: ! Wind Gusts: Comments: LELS in cellar are checked twice every day Printed: 19:52 13-Sep-10 RIMBase 5.1.1.177 Page:2 of 2 Daily Drilling Report Geothermal Resource Group kl$4* Well ID: AGP TG-4 Well Name:South Elbow Well Field: Hot Springs Bay Vs County:Aleutians East State:AK Country: United States Report No: 10 Report For 18-Aug-10 Operator: City Of Akutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 600 Drilling Days: 8 actual/24 plan RKB Elevation: 5.00 County: Aleutians East Vertical Depth(ft): 600 Days On Location: 10 Last Casing: 3.5 at 596,Test to Field: Hot Springs Bay Hole Made: 53 Spud Date: 11-Aug-10 Next Casing: 1.660 at 1,500 Working Interest: Drilling Hrs: 3.0 Average ROP: 17.7 Last BOP Test: 16-Aug-10 Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 4 Total: 18 Current Operations: Slack off and Unscrew top jt,Close master valve and test csg to 750 psi,Test good,Open master valve and install test plug,Test BOPE and valves.low-200-High 750,M/U 2.98 core bit and pick up NQ rods and RIH @ 06:00 hr;s Planned Operations: Run in hole w/NQ and tag TOC,Rig up and run TP log,Clean out CMT,FC and drill 20'of new hole to 620',Conduct leak off test @ 620',Core 2.98 hole f/620' Toolpusher: Dave Griggs Wellsite Supervisors: Dan Darnell Tel No.: 1-907-444-1777 Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 3:00 3.00 600 DRIL Cored 3.78"hole f/547'to 600'with full returns.flow line temp 107 deg F 3:00 4:00 1.00 600 SURV Circ and survey @ 600' 2.5 deg 4:00 5:30 1.50 600 TRPO POOH laying out HQ rods f/600' 5:30 6:00 0.50 600 CASE Rig up to run 3 1/2"csg 6:00 12:30 6.50 600 CASE Run 59 jts of 3-1/2"HQ parallel wall csg with float collar between the first and second joint to 596' • 12:30 15:30 3.00 600 CIRC Circ and condition hole.Flow line temp 107.9 deg F 15:30 16:30 1.00 600 CMTP Mix and pump 13.5#cement w/100%excess,Cement to surface,CIP @ 16:30 16:30 0:00 7.50 600 WOC WOC,Lift and clean around well head and stack. Casing Information Type Size Top MD Top TVD Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.625 5 5 38 38 COND 10.000 FULL 4.500 5 5 186 186 SURF 5.500 832.00 FULL 3.500 5 5 - 596 596 INTI 3.780 1012.00 Cost/AFE Information AFE No AFE Description AFE Amount Daily Mud Well Mud Daily Total Well Total %Spent No AFE Assigned 0 0 0 55,067 398,029 Totals$: 0 0 0 55,067 398,029 Mud Information Gels Temp Density Vis PV YP Filt. Cake pH Solids Oil Water Sand Chloride Calcium 10s 10m 30m In Out 18-Aug-10 02:00 Sample from Mud Pits 8.40 44 9 0 72 107 Bit/BHA Information Depth This Run R.O.P. Mud Pump No Run Make Model Diam In Dist Hrs Avg Max WOB RPM Torque Wt Flow Press J.Vel P.Drp HHP JIF 5 1 FORDIF Volcan 3.780 510 90 7 12.9 15.0 1100 8 35 210 Jets: Out: 600 Grade: Cutter: / Dull: / Wear: Brgs: Gge: Pull: Drilling Parameters ROP WOB(lbs) RPM Torque(ft lbs) Flow(gals/min) From To Avg Max Avg Max Avg Max Avg Max Avg Max PSI 547 600 10.0 15.0 1000 1200 35 45 210 Annular Velocity: Drill Collars: 404.0 Drill Pipe: 404.0 Comments: Cored 3.78"hole f/547'to 600'with full returns.flow line temp 107 deg F Survey Information Survey Meas. Vertical Coordinates Type Depth Inc. Azimuth TVD Closure Section N-S E-W D.L.S. TOTCO 600.0 2.00 Printed: 19:52 13-Sep-10 RIMBase 5.1.1.177 Page: 1 of 2 Vv Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-4 Well Name: South Elbow Well Field: Hot Springs Bay Va County:Aleutians East State:AK Country: United States Report No: 10 Report For 18-Aug-10 Mud Log Information Depth(ft) ND(ft) Gas(Units) Gas Drilling Pore Mud Shale ROP From To From To Avg Max at Depth Connect. Trip Exp. Press Dens. Dens. Shale Sand 547 600 Formation Name: Lithology: Rig Information Equipment Problems: None Location Condition: Wet,muddy. Transport: The inventory is whats on the rig only Inventory Bulk Used This Received This Bulk Used This Received This Material Report Period Report Period Inventory Material Report Period Report Period Inventory POLY VIS 0.75 1 TORKEASE 4.5 EZ-MUD 14 SODA ASH 98 BARITE 44 GEL 6 10 CaC 42 AQUA PAC 19 CEMENT 34 35 5 DEFOAM14 5 DESCO CF 0.5 4.5 ZINC 1 CAUSTIC 5.75 Safety Information Meetings/Drills Time Description Safety 30 Crews held pre-tour safety meeting First Aid: Medical: Lost Time Accidents: Days Since LTA: 9 BOP Test Crownamatic Check Weather Information Sky Condition: Visibility: Air Temperature: Bar.Pressure: Wind Speed/Dir: / Wind Gusts: Comments: LELS in cellar are checked twice every day Printed: 19:52 13-Sep-10 RIMBase 5.1.1.177 Page:2 of 2 Daily Drilling Report Geothermal Resource Group 1)$ Well ID: AGP TG-4 Well Name:South Elbow Well Field: Hot Springs Bay Va County:Aleutians East State:AK Country: United States Report No: 11 Report For 19-Aug-10 Operator: City Of Akutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 793 Drilling Days: 9 actual/24 plan RKB Elevation: 5.00 County: Aleutians East Vertical Depth(ft): 793 Days On Location: 11 Last Casing: 3.5 at 596,Test to Field: Hot Springs Bay Hole Made: 193 Spud Date: 11-Aug-10 Next Casing: 1.660 at 1,500 Working Interest: Drilling Hrs: 8.5 Average ROP: 22.7 Last BOP Test: 19-Aug-10 Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 5 Total: 19 Current Operations: Cored 3.032"hole f/793't1923'w/full returns.Flow line temp= 105 deg F. 923'@ 06:00 hrs. Planned Operations: Continue to core 3.032 hole with surveys to 1500'. Toolpusher: Dave Griggs Wellsite Supervisors: Dan Darnell Tel No.: 1-907-444-1777 Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 1:00 1.00 600 WOC WOC.Nippled up BOP. 1:00 5:00 4.00 600 BOPT Tested annular preventer and valves to a low of 200 psi and high of 750 psi.Good 1 tests. 5:00 5:30 0.50 600 OTHER Changed rod handling equipment over to NQ. 5:30 8:00 2.50 600 TRPI M/U 3.032" 8 D2 core bit and NQ core barrel and rods. RIH and tagged TOC @ 566'. 8:00 11:00 3.00 600 SURV Rigged up and ran PT survey tool to 544'. Bottom hole temp=265 deg F I/ 11:00 11:30 0.50 600 CIRC Circ and cooled well @ 566'. 11:30 13:30 2.00 600 CMTD Cleaned out cement f/566'. 13:30 15:00 1.50 620 DRIL Cored new 3.032"hole f/600't1620'. 15:00 16:00 1.00 600 FIT Conducted leak off test.Pumped in 3/4 gal intervals to 596 psi surface pressure before halting test.Fracture Gradient in excess of 1.3 psi/ft. 16:00 20:00 4.00 703 DRIL Cored 3.032"hole f/620'U703'with full returns.Flow line temp=105 deg F. 20:00 21:00 1.00 600 SURV Surveyed @ 703'.4 deg. 21:00 0:00 3.00 793 DRIL Cored 3.032 hole f/703't/793'with full returns.Flow line temp=105 deg F. Comments Nippled up BOP and tested. M/U NQ core tools and RIH. Cleaned out cement and cored new hole to 620'. Performed LOT-halted test at 596 psi surface pressure/1.3 psi gradient. Cored ahead t/793'. Casing Information Type Size Top MD Top TVD Bottom MD Bottom ND Hole Section Avg OH Diam LOT FULL 6.625 5 5 38 38 COND 10.000 FULL 4.500 5 5 186 186 SURF 5.500 832.00 FULL 3.500 5 5 596 596 INTI 3.780 1012.00 Cost/AFE Information AFE No AFE Description AFE Amount Daily Mud Well Mud Daily Total Well Total %Spent No AFE Assigned 0 0 0 45,771 443,800 Totals$: 0 0 0 45,771 443,800 Mud Information Gels Temp Density Vis PV YP Filt. Cake pH Solids Oil Water Sand Chloride Calcium 10s 10m 30m In Out 19-Aug-10 20:00 Sample from Mud Pits 8.40 37 8 0 75 105 Bit/BHA Information Depth This Run R.O.P. Mud Pump No Run Make Model Diam In Dist Hrs Avg Max WOB RPM Torque Wt Flow Press J.Vel P.Drp HHP JIF 6 1 ADT NQRS8 3.032 600 193 8.5 22.7 25.0 1200 8 35 210 Jets: Out: 1500 Grade: Cutter: / Dull: / Wear: Brgs: Gge: Pull: Printed: 19:52 13-Sep-10 RIMBase 5.1.1.177 Page: 1 of 2 Daily Drilling Report Geothermal Resource Group fr0 Well ID: AGP TG-4 Well Name:South Elbow Well Field: Hot Springs Bay Va County:Aleutians East State:AK Country: United States Report No: 11 Report For 19-Aug-10 Drilling Parameters ROP WOB(lbs) RPM Torque(ft lbs) Flow(gals/min) From To Avg Max Avg Max Avg Max Avg Max Avg Max PSI 600 793 15.0 25.0 1100 1200 35 35 210 Annular Velocity: Drill Collars: 314.0 Drill Pipe: 314.0 Comments: Core 3.032 hole f/600'to 793',Flow line temp 105',dev survey's came back f/4 deg to 1/2 deg in 200' Survey Information Survey Meas. Vertical Coordinates Type Depth Inc. Azimuth TVD Closure Section N-S E-W D.L.S. TOTCO 703.0 4.00 TOTCO 803.0 2.50 TOTCO 903.0 0.50 Rig Information Equipment Problems: None.The inventory is what is on the rig only. Location Condition: Wet,muddy. Transport: Inventory Bulk Used This Received This Bulk Used This Received This Material Report Period Report Period Inventory Material Report Period Report Period Inventory DEFOAM14 5 DESCO CF 4.5 POLY VIS 1 0 TORKEASE 1 3.5 CEMENT 5 EZ-MUD 1 13 ZINC 1 CAUSTIC 5.75 BARITE 44 GEL 10 CaC 42 AQUA PAC 19 SODA ASH 98 Safety Information Meetings/Drills Time Description Safety 30 Crews held pre-tour safety meeting.LELS in cellar are checked twice every day. First Aid: Medical: Lost Time Accidents: Days Since LTA: 10 ❑✓ BOP Test ❑ Crownamatic Check Weather Information Sky Condition: Cloudy/Rain Visibility: Air Temperature: 46.0 degF Bar.Pressure: Wind Speed/Dir: / Wind Gusts: Printed: 19:52 13-Sep-10 RIMBase 5.1.1.177 Page:2 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-4 Well Name:South Elbow Well Field: Hot Springs Bay V2 County:Aleutians East State:AK Country: United States Report No: 12 Report For 20-Aug-10 Operator: City OfAkutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 1,243 Drilling Days: 10 actual/24 plan RKB Elevation: 5.00 County: Aleutians East Vertical Depth(ft): 1,243 Days On Location: 12 Last Casing: 3.5 at 596,Test to Field: Hot Springs Bay Hole Made: 450 Spud Date: 11-Aug-10 Next Casing: 1.660 at 1,500 Working Interest: Drilling Hrs: 20.0 Average ROP: 22.5 Last BOP Test: 19-Aug-10 Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 5 Total: 19 Current Operations: Cored 3.032"hole f/1243't/1373'with full returns.Flow line temp= 105 deg. BHT=323 deg.F. Planned Operations: Finish coring well to 1500 ft. Run Pressure/Temperature surveys. Toolpusher: Dave Griggs Wellsite Supervisors: Randy Baldwin Tel No.: 1-907-444-1777 Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 0:30 0.50 803 DRIL Cored 3.032"hole f/793't/803'with full returns.Flow line temp=105 deg F. 0:30 1:30 1.00 803 SURV Surveyed @ 803'.2.25 deg. 1:30 4:30 3.00 903 DRIL Cored 3.032"hole f/803't/903'with full returns.Flow line temp= 105 deg F. 4:30 5:30 1.00 903 SURV Surveyed @ 903'..5 deg. 5:30 6:00 0.50 903 CIRC Condition hole. 6:00 11:00 5.00 1,001 DRIL Cored 3.032"hole f/903't/1001'with full returns.Flow line temp= 105 deg 11:00 11:30 0.50 1,001 SURV Surveyed @ 1001 ft. 4.00 deg. BHT=287 deg.F. 11:30 15:00 3.50 1,103 DRIL Cored 3.032"hole f/1001't/1103'with full returns.Flow line temp= 105 deg 15:00 15:30 0.50 1,103 SURV Surveyed @ 1103 ft. 2.25 deg. BHT=279 deg.F. 15:30 21:30 6.00 1,203 DRIL Cored 3.032"hole f/1103't/1203'with full returns.Flow line temp= 105 deg 21:30 22:00 0.50 1,203 SURV Surveyed @ 1203 ft, 1.25 deg. BHT=305 deg F. 22:00 0:00 2.00 1,243 DRIL Cored 3.032"hole f/1203't/1243'with full returns.Flow line temp= 105 deg Comments Cored 3.032"hole f/793't/1243'with full returns.Survey every 100 ft. Flow line temp=105 deg BHT=305 deg.F. Casing Information Type Size Top MD Top ND Bottom MD Bottom ND Hole Section Avg OH Diam LOT FULL 6.625 5 5 38 38 COND 10.000 FULL 4.500 5 5 186 186 SURF 5.500 832.00 FULL 3.500 5 5 596 596 INTI 3.780 1012.00 Cost/AFE Information AFE No AFE Description AFE Amount Daily Mud Well Mud Daily Total Well Total %Spent No AFE Assigned 0 0 0 61,415 505,215 Totals$: 0 0 0 61,415 505,215 Mud Information % Gels Temp Density Vis PV YP Filt. Cake pH Solids Oil Water Sand Chloride Calcium 10s 10m 30m In Out 20-Aug-10 20:00 at Depth 1,203 ft Sample from Mud Pits 8.40 37 8 0 80 105 Bit/BHA Information Depth This Run R.O.P. Mud Pump No Run Make Model Diam In Dist Hrs Avg Max WOB RPM Torque Wt Flow Press J.Vel P.Drp HHP JIF 6 1 ADT NQRS8 3.032 600 643 28.5 22.6 25.0 1200 8 35 250 Jets: Out: 1500 Grade: Cutter: / Dull: / Wear: Brgs: Gge: Pull: Drilling Parameters ROP WOB(lbs) RPM Torque(ft lbs) Flow(gals/min) From To Avg Max Avg Max Avg Max Avg Max Avg Max PSI 793 1,293 22.0 25.0 1100 1200 35 35 250 Annular Velocity: Drill Collars: 314.0 Drill Pipe: 314.0 Comments: Cored 3.032"hole f/793't/1243'with full returns.Survey every 100 ft. Flow line temp= 105 deg BHT=305 deg.F. Printed: 19:52 13-Sep-10 RIMBase 5.1.1.177 Page: 1 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-4 Well Name: South Elbow Well Field: Hot Springs Bay Va County:Aleutians East State: AK Country: United States Report No: 12 Report For 20-Aug-10 Survey Information Survey Meas. Vertical Coordinates Type Depth Inc. Azimuth TVD Closure Section N-S E-W D.L.S. TOTCO 1,001.0 4.00 TOTCO 1,103.0 2.25 TOTCO 1,203.0 1.25 Rig Information Equipment Problems: None.The inventory is what is on the rig only. Location Condition: Wet,muddy. Transport: Solids Control Information Inventory Bulk Used This Received This Bulk Used This Received This Material Report Period Report Period Inventory Material Report Period Report Period Inventory ZINC 1 CAUSTIC 5.75 BARITE 44 GEL 10 CaC 42 AQUA PAC 19 CEMENT 5 POLY VIS 0 TORKEASE 3.5 20 20 EZ-MUD 12 1 SODA ASH 98 DEFOAM14 5 DESCO CF 4.5 Safety Information Meetings/Drills Time Description Safety 30 Crews held pre-tour safety meeting. LELS in cellar are checked twice every day First Aid: Medical: Lost Time Accidents: Days Since LTA: 11 BOP Test Crownamatic Check Weather Information Sky Condition: Cloudy Visibility: Air Temperature: 55.0 degF Bar.Pressure: Wind Speed/Dir: 0/ Wind Gusts: Printed: 19:52 13-Sep-10 RIMBase 5.1.1.177 Page:2 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-4 Well Name:South Elbow Well Field: Hot Springs Bay Va County:Aleutians East State:AK Country: United States Report No: 13 Report For 21-Aug-10 Operator: City Of Akutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 1,500 Drilling Days: 11 actual/24 plan RKB Elevation: 5.00 County: Aleutians East Vertical Depth(ft): 1,500 Days On Location: 13 Last Casing: 3.5 at 596,Test to Field: Hot Springs Bay Hole Made: 257 Spud Date: 11-Aug-10 Next Casing: 1.660 at 1,500 Working Interest: Drilling Hrs: 13.0 Average ROP: 19.8 Last BOP Test: 19-Aug-10 Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 5 Total: 19 Current Operations: Waited for well to heat up.Started running 1st Pressure/Temperature log @ 04:30 hrs. Planned Operations: Run Pressure/Temperature logs. Toolpusher: Dave Griggs Wellsite Supervisors: Randy Baldwin Tel No.: 1-907-444-1777 Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 4:00 4.00 1,303 DRIL Cored 3.032"hole f/1243'U1303'with full returns.Flow line temp= 105 deg 4:00 4:30 0.50 1,303 SURV Surveyed at 1303 ft. 1 deg. BHT=323 deg F. 1 4:30 8:00 3.50 1,403 DRIL Cored 3.032"hole f/1303't/1403'with full returns.Flow line temp= 105 deg 8:00 8:30 0.50 1,403 SURV Surveyed at 1403 ft. 0.5 deg. BHT=330 deg F. 8:30 14:00 5.50 1,500 DRIL Cored 3.032"hole f/1403'U1500'with full returns.Flow line temp= 105 deg 14:00 14:30 0.50 1,500 SURV Surveyed at 1500 ft. 2 deg. BHT=323 deg.F. r 14:30 16:00 1.50 1,500 CIRC Circulate and clean hole. 16:00 16:30 0.50 1,500 COOL Mix and pump 9.5 ppg CaCl2 water. 16:30 0:00 7.50 1,500 TEST Waiting on well to heat up for 12 hrs prior to pressure and temperature logging. 1' Comments Cored 3.032"hole f/1243'U1500'with full returns.Flow line temp= 105 deg. BHT=323 deg F. Circulate hole clean,Change hole over to 9.5 CaCl2 water.Waiting on well to heat up for 12 hrs prior to pressure and temperature logging. Casing Information Type Size Top MD Top TVD Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.625 5 5 38 38 COND 10.000 FULL 4.500 5 5 186 186 SURF 5.500 832.00 FULL 3.500 5 5 596 596 INTI 3.780 1012.00 Cost/AFE Information AFE No AFE Description AFE Amount Daily Mud Well Mud Daily Total Well Total %Spent No AFE Assigned 0 0 0 49,621 554,836 Totals$: 0 0 0 49,621 554,836 Mud Information Gels Temp Density Vis PV YP Filt. Cake pH Solids Oil Water Sand Chloride Calcium 10s 10m 30m In Out 21-Aug-10 15:00 at Depth 1,500 ft Sample from Mud Pits 8.50 37 8 90 105 Bit/BHA Information Depth This Run R.O.P. Mud Pump No Run Make Model Diam In Dist Hrs Avg Max WOB RPM Torque Wt Flow Press J.Vel P.Drp HHP JIF 6 1 ADT NQRS8 3.032 600 900 41.5 21.7 1100 8 35 250 Jets: Out: 1500 Grade: Cutter: / Dull / Wear: Brgs: Gge: Pull: Drilling Parameters ROP WOB(lbs) RPM Torque(ft lbs) Flow(gals/min) From To Avg Max Avg Max Avg Max Avg Max Avg Max PSI 1,243 1,500 21.0 25.0 1100 1200 35 35 250 Annular Velocity: Drill Collars: 314.0 Drill Pipe: 314.0 Comments: Cored 3.032"hole f/793't/1243'with full returns.Survey every 100 ft. Flow line temp= 105 deg BHT=305 deg.F. Printed: 19:52 13-Sep-10 RIMBase 5.1.1.177 Page: 1 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-4 Well Name: South Elbow Well Field: Hot Springs Bay Va County:Aleutians East State:AK Country: United States Report No: 13 Report For 21-Aug-10 Survey Information Survey Meas. Vertical Coordinates Type Depth Inc. Azimuth TVD Closure Section N-S E-W D.L.S. TOTCO 1,303.0 1.00 TOTCO 1,403.0 0.50 TOTCO 1,500.0 2.00 Rig Information Equipment Problems: None.The inventory is what is on the rig only. Location Condition: Wet,muddy. Transport: Inventory Bulk Used This Received This Bulk Used This Received This Material Report Period Report Period Inventory Material Report Period Report Period Inventory ZINC 1 CAUSTIC 5.75 BARITE 44 GEL 10 CaC 42 AQUA PAC 19 CEMENT 5 POLY VIS 0 TORKEASE 10 10 EZ-MUD 1 0 SODA ASH 98 DEFOAM14 5 DESCO CF 4.5 Safety Information Meetings/Drills Time Description Safety 30 Crews held pre-tour safety meeting. LELS in cellar are checked twice every day. First Aid: Medical: Lost Time Accidents: Days Since LTA: 12 ❑ BOP Test Crownamatic Check Weather Information Sky Condition: Cloudy Visibility: 3 Air Temperature: 53.0 degF Bar.Pressure: Wind Speed/Dir: 10/NE Wind Gusts: 15 Printed: 19:52 13-Sep-10 RIMBase 5.1.1.177 Page:2 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-4 Well Name: South Elbow Well Field: Hot Springs Bay Va County:Aleutians East State:AK Country: United States Report No: 14 Report For 22-Aug-10 Operator: City Of Akutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 1,500 Drilling Days: 12 actual/24 plan RKB Elevation: 5.00 County: Aleutians East Vertical Depth(ft): 1,500 Days On Location: 14 Last Casing: 3.5 at 596,Test to Field: Hot Springs Bay Hole Made: 0 Spud Date: 11-Aug-10 Next Casing: 1.660 at 1,500 Working Interest: Drilling Hrs: 0 Average ROP: 0 Last BOP Test: 19-Aug-10 Personnel: Operator: 3 Contractor: 7 Service: 5 Other: 4 Total: 19 Current Operations: Running 36 hour Pressure/Temperature log. Planned Operations: Finish PT logs,change hole over to water,POOH. Unload well. Toolpusher: Dave Griggs Wellsite Supervisors: Randy Baldwin Tel No.: 1-907-444-1777 Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 4:30 4.50 1,500 TEST Allow well to heat up for 12 hour Pressure/Temperature logs. 4:30 11:30 7.00 1,500 TEST Opened well&began 12 hour Pressure/Temperature logs. Initial stop at 50'and 100', followed by 20'stops to TD. 11:30 16:30 5.00 1,500 TEST Allow well to heat up for 24 hour Pressure/Temperature logs. 16:30 23:30 7.00 1,500 TEST Opened well&began 24 hour Pressure/Temperature logs. Initial stop at 50'and 100', followed by 20'stops to TD. 23:30 0:00 0.50 1,500 TEST Allow well to heat up for 36 hour Pressure/Temperature logs. • Comments Run 12 and 24 hour Pressure/Temperature logs. Casing Information Type Size Top MD Top TVD Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.625 5 5 38 38 COND 10.000 FULL 4.500 5 5 186 186 SURF 5.500 832.00 FULL 3.500 5 5 596 596 INTI 3.780 1012.00 Cost/AFE Information AFE No AFE Description AFE Amount Daily Mud Well Mud Daily Total Well Total %Spent No AFE Assigned 0 0 0 34,985 589,821 Totals$: 0 0 0 34,985 589,821 Mud Information % Gels Temp Density Vis PV YP Filt. Cake pH Solids Oil Water Sand Chloride Calcium 10s 10m 30m In Out 22-Aug-10 17:00 at Depth 1,500 ft Sample from Mud Pits,Type:Water 8.33 28 6.5 0 Bit/BHA Information Depth This Run R.O.P. Mud Pump No Run Make Model Diam In Dist Hrs Avg Max WOB RPM Torque Wt Flow Press J.Vel P.Drp HHP JIF 6 1 ADT NQRS8 3.032 600 900 41.5 0.0 0.0 0 0 0 8 0 0 Jets: Out: 1500 Grade: Cutter: / Dull: / Wear: Brgs: Gge: Pull: Rig Information Equipment Problems: None.The inventory is what is on the rig only. Location Condition: Wet,muddy. Transport: Printed: 19:52 13-Sep-10 RIMBase 5.1.1.177 Page: 1 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-4 Well Name:South Elbow Well Field: Hot Springs Bay Va County:Aleutians East State:AK Country: United States Report No: 14 Report For 22-Aug-10 Inventory Bulk Used This Received This Bulk Used This Received This Material Report Period Report Period Inventory Material Report Period Report Period Inventory ZINC 1 CAUSTIC 5.75 BARITE 44 GEL 10 CaC 42 AQUA PAC 19 CEMENT 5 POLY VIS 0 TORKEASE 10 EZ-MUD 0 SODA ASH 98 DEFOAM14 5 DESCO CF 4.5 Safety Information Meetings/Drills Time Description Safety 30 Crews held pre-tour safety meeting. LELS in cellar are checked twice every day. First Aid: Medical: Lost Time Accidents: Days Since LTA: 13 ❑ BOP Test Crownamatic Check Weather Information Sky Condition: Partly cloudy Visibility: 5 Air Temperature: 55.0 degF Bar.Pressure: Wind Speed/Dir: 5/E Wind Gusts: 15 Printed: 19:52 13-Sep-10 R/MBase 5.1.1.177 Page:2 of 2 Daily Drilling Report Geothermal Resource Group Pt0 Well ID: AGP TG-4 Well Name:South Elbow Well Field: Hot Springs Bay V8 County:Aleutians East State:AK Country: United States Report No: 15 Report For 23-Aug-10 Operator: City Of Akutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 1,500 Drilling Days: 13 actual/24 plan RKB Elevation: 5.00 County: Aleutians East Vertical Depth(ft): 1,500 Days On Location: 15 Last Casing: 3.5 at 596,Test to Field: Hot Springs Bay Hole Made: 0 Spud Date: 11-Aug-10 Next Casing: 1.660 at 1,500 Working Interest: Drilling Hrs: 0 Average ROP: 0 Last BOP Test: 19-Aug-10 Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 5 Total: 19 Current Operations: Stage in hole,unloading with air to 1100 ft. Planned Operations: Perform injection test.Run 1 1/4 inch tubing. Toolpusher: Dave Griggs Wellsite Supervisors: Randy Baldwin Tel No.: 1-907-444-1777 Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 4:30 4.50 1,500 TEST Allow well to heat up for 36 hour Pressure/Temperature logs. 4:30 11:30 7.00 1,500 TEST Opened well&began 36 hour Pressure/Temperature logs. Initial stop at 50'and 100', ✓ followed by 20'stops to TD. 11:30 12:00 0.50 1,500 CIRC Circulate hole over to fresh water. 12:00 13:30 1.50 1,500 TRPO POOH with bit and NQ rod. 13:30 0:00 10.50 1,500 TEST Close master valve,allow well to heat up. Comments Run 36 hour Pressure/Temperature log.Change hole over to water.POOH. Close master valve,allow well to heat up. Casing Information Type Size Top MD Top TVD Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.625 5 5 38 38 COND 10.000 FULL 4.500 5 5 186 186 SURF 5.500 832.00 FULL 3.500 5 5 596 596 INTI 3.780 1012.00 Cost/AFE Information AFE No AFE Description AFE Amount Daily Mud Well Mud Daily Total Well Total %Spent No AFE Assigned 0 0 0 34,985 624,806 Totals$: 0 0 0 34,985 624,806 Mud Information Gels Temp Density Vis PV YP Filt. Cake pH Solids Oil Water Sand Chloride Calcium 10s 10m 30m In Out 23-Aug-10 17:00 at Depth 1,500 ft Sample from Mud Pits,Type:Water 8.33 27 7 100 Bit/BHA Information Depth This Run R.O.P. Mud Pump No Run Make Model Diam In Dist Hrs Avg Max WOB RPM Torque Wt Flow Press J.Vel P.Drp HHP JIF 6 1 ADT NQRS8 3.032 600 900 41.5 0.0 0.0 0 0 0 8 35 200 Jets: Out: 1500 Grade: Cutter: / Dull: / Wear: Brgs: Gge: Pull: Rig Information Equipment Problems: None.The inventory is what is on the rig only. Location Condition: Wet,muddy. Transport: Printed: 19:52 13-Sep-10 RIMBase 5.1.1.177 Page: 1 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-4 Well Name:South Elbow Well Field: Hot Springs Bay V8 County:Aleutians East State:AK Country: United States Report No: 15 Report For 23-Aug-10 Inventory Bulk Used This Received This Bulk Used This Received This Material Report Period Report Period Inventory Material Report Period Report Period Inventory ZINC 1 CAUSTIC 5.75 BARITE 44 GEL 10 CaC 42 AQUA PAC 19 CEMENT 5 POLY VIS 0 TORKEASE 10 EZ-MUD 0 SODA ASH 98 DEFOAM14 5 DESCO CF 4.5 Safety Information Meetings/Drills Time Description Safety 30 Crews held pre-tour safety meeting.LELS in cellar are checked twice every day. First Aid: Medical: Lost Time Accidents: Days Since LTA: 14 El BOP Test Crownamatic Check Weather Information Sky Condition: Partly coludy Visibility: 10 Air Temperature: 55.0 degF Bar.Pressure: Wind Speed/Dir: 10/SW Wind Gusts: 15 Printed: 19:52 13-Sep-10 RIMBase 5.1.1.177 Page:2 of 2 Daily Drilling Report Geothermal Resource Group I* Well ID: AGP TG-4 Well Name:South Elbow Well Field: Hot Springs Bay Vo County:Aleutians East State:AK Country: United States Report No: 16 Report For 24-Aug-10 Operator: City Of Akutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 1,500 Drilling Days: 14 actual/24 plan RKB Elevation: 5.00 County: Aleutians East Vertical Depth(ft): 1,500 Days On Location: 16 Last Casing: 1.66 at 1,491 Field: Hot Springs Bay Hole Made: 0 Spud Date: 11-Aug-10 Next Casing: Working Interest: Drilling Hrs: 0 Average ROP: 0 Last BOP Test: 19-Aug-10 Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 5 Total: 19 Current Operations: Waiting on daylight. FINAL REPORT. Planned Operations: Continue demob of rig. Toolpusher: Dave Griggs Wellsite Supervisors: Randy Baldwin Tel No.: 1-907-444-1777 Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 6:00 6.00 1,500 UNLOAD Stage in hole to 1100 ft.in 100/ft increments,unloading well with air.Getting approx 4 to 5 gals/min.of water back after intial blow down. 6:00 8:00 2.00 1,500 UNLOAD Unload well with air at 1100 ft.Let blow for 1 hour.Shut air off,well quit flowing. • 8:00 9:00 1.00 1,500 TRPO Pull up to shoe. 9:00 12:00 3.00 1,500 EVAL Perform injection test at 1 gal/min,2 gal/min,and 2.5 gal/min. 12:00 13:00 1.00 1,500 TRPO POOH. 13:00 16:00 3.00 1,500 TRPI RIH with 1 1/4 inch tubing t/1491 ft.with check valve on bottom. 16:00 17:30 1.50 1,500 BOPND Nipple down BOPs. 17:30 18:00 0.50 1,500 BOPO Install wellhead. Secure well. Release rig. 18:00 20:00 2.00 1,500 MOB Demob rig,lay mast over. 20:00 0:00 4.00 1,500 OTHER Waiting on daylight. Comments Unload well to 1100 ft.with air.Perform injection test.RIH with 1 1/4 inch tubing to 1491 ft. Nipple down BOPs, Install wellhead.Secure well,and demob rig. Casing Information Type Size Top MD Top ND Bottom MD Bottom ND Hole Section Avg OH Diam LOT FULL 6.625 5 5 38 38 COND 10.000 FULL 4.500 5 5 186 186 SURF 5.500 832.00 FULL 3.500 5 5 596 596 INTI 3.780 1012.00 HNG DN 1.660 0 0 1491 1491 2.980 Cost/AFE Information AFE No AFE Description AFE Amount Daily Mud Well Mud Daily Total Well Total %Spent No AFE Assigned 0 0 0 208,345 833,151 Totals$: 0 0 0 208,345 833,151 Rig Information Equipment Problems: None.The inventory is what is on the rig only. Location Condition: Wet,muddy. Transport: Inventory Bulk Used This Received This Bulk Used This Received This Material Report Period Report Period Inventory Material Report Period Report Period Inventory DESCO CF 4.5 ZINC 1 CAUSTIC 5.75 BARITE 44 GEL 10 CaC 42 AQUA PAC 19 CEMENT 5 POLY VIS 0 TORKEASE 10 EZ-MUD 0 SODA ASH 98 DEFOAM14 5 Printed: 19:52 13-Sep-10 RIMBase 5.1.1.177 Page: 1 of 2 Daily Drilling Report Geothermal Resource Group f k„ Well ID: AGP TG-4 Well Name: South Elbow Well Field: Hot Springs Bay V2 County: Aleutians East State:AK Country: United States Report No: 16 Report For 24-Aug-10 Safety Information Meetings/Drills Time Description Safety 30 Crews held pre-tour safety meeting.LELS in cellar are checked twice every day. First Aid: Medical: Lost Time Accidents: Days Since LTA: 15 BOP Test Crownamatic Check Weather Information Sky Condition: Cloudy,light rain. Visibility: 10 Air Temperature: 53.0 degF Bar.Pressure: Wind Speed/Dir: 15/NE Wind Gusts: 25 Printed: 19:52 13-Sep-10 RIMBase 5.1.1.177 Page:2 of 2 Directional Survey Report Geothermal Resource Group Well ID: AGP TG-4 Well Name: South Elbow Well Field: Hot Springs Bay Va County: Aleutians East State: AK Country: United States Survey Meas. Coordinates Vertical Dog Leg Type Depth Inc. Azimuth TVD N-S E-W Closure Section Severity Well Bore: Original Well Bore Plane of Vertical Section: 0 **Tieln 0.0 0.00 0 0.0 0.0 0.0 0.0 TOTCC 103.0 2.00 TOTCC 208.0 0.75 TOTCC 301.0 2.50 TOTCC 403.0 2.50 TOTCC 503.0 2.00 TOTCC 600.0 2.00 TOTCC 703.0 4.00 TOTCC 803.0 2.50 TOTCC 903.0 0.50 TOTCC 1,001.0 4.00 TOTCC 1,103.0 2.25 TOTCC 1,203.0 1.25 TOTCC 1,303.0 1.00 TOTCC 1,403.0 0.50 TOTCC 1,500.0 2.00 Calculations using Minimum Curvature Method Printed: 19:53 13-Sep-10 R/MBase 5.1.1.177 Page: 1 of 1 Page 1 of 1 • Regg, James B (DOA) 7-40-0-73 From: Alan Bailey [alanbailey@geothermalresourcegroup.com] Sent: Friday, August 20, 2010 3:30 PMe�,� ;fret° To: Regg, James B (DOA) j Cc: 'dan darnell'; 'Randy Baldwin'; 'Amanda Kolker'; 'Ray Mann'; 'Robert Kirkman' Subject: BOP Worksheet Attachments: HSB4 8.19.10 BOP Tests.xls; HSB4 8.19.10 LOT Test.xls; Major Drilling LF90 08-19-10.xls Jim, Here's the worksheet from the test we performed yesterday. Also attached is the graph from the leakoff test. Given current circumstances,this may be the last test we perform on this well. I expect to TD later today or tomorrow sometime, and testing should take about 3 days. Alan Bailey Geothermal Resource Group, Inc. alanbailey@geothermalresourcegroup.com 760-341-0186 Office 760-341-9673 Fax 775-304-3253 Cell alan.bailey6l/775-583-4662 Skype www.geothermalresourcegroup.com r X'! Untitled L 8/20/2010 STATE OF ALASKA 01/25/10 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: jim.regq cAalaska.gov doa.aogcc.prudhoe.bavaalaska.gov phoebe.brooksna.alaska.gov Contractor: r Rig No.: L-F9 O DATE: 8/19/10 Rig Rep.: David Griggs Rig Phone: 907-444-1777 Rig Fax: NA Operator: City of Akutan Op. Phone: Op. Fax: NA Rep.: Dan Darnell E-Mail toolpusherdan@yahoo.com Well Name: South Elbow#4 PTD# 2100730 Operation: Drlg: X Workover: Explor.: Test: Initial: Weekly: X Bi-Weekly Test Pressure: Rams: Annular: 200/750 Valves: 200/750 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly 0 NA Housekeeping: P Dr!. Rig P Lower Kelly 0 NA PTD On Location P Hazard Sec. P Ball Type 0 NA Standing Order Posted P Misc NA Inside BOP 0 NA FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank NA NA Annular Preventer 1 7.0625 Regar P Pit Level Indicators NA NA #1 Rams 0 NA Flow Indicator NA NA #2 Rams 0 NA Meth Gas Detector P P #3 Rams 0 NA H2S Gas Detector P P #4 Rams 0 NA MS Misc NA NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln. Valves 0 NA Inside Reel valves 0 NA HCR Valves 1 3.125 3M P Kill Line Valves 1 1.25 P Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 1 3.125 3M P Time/Pressure Test Result System Pressure 3000 P CHOKE MANIFOLD: Pressure After Closure 2800 P Quantity Test Result 200 psi Attained 6 P No. Valves 0 NA Full Pressure Attained 40 P Manual Chokes 0 NA Blind Switch Covers: All stations No Hydraulic Chokes 0 NA Nitgn. Bottles (avg): 2400 CH Misc 0 NA ACC Misc 1 NA Test Results Number of Failures: 0 Test Time: 2.0 Hours Repair or replacement of equipment will be made within 0 days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Supervisor at: jim.regq@alaska.gov Remarks: Test was performed due to the need to partially nipple down following a cement job. It took 6 sec for the anular preventor to close and 40 sec to recharge back up f/2800 to 3000 psi,Every thing else is still the same,If you have any questions please send me an email c toolpusherdan@yahoo.com 24 HOUR NOTICE GIVEN YES NO X Waived By Jeff Jones Date Time Witness Test start 03:00 Finish 05:00 PLB 01/25/10 2010-0819 BOP NANA LF90 Akutan SouthElbow-4.xls I' ► a N c O, v 1 v I L11-_I SO:S OTOz/6I/8 _= Z05 OTOZ/61/8 6S:b O1OZ/61/8 v LS 17 OIOZ/61/8 as a _ i bS:b OIOZ/61/8 d a: CO ''., CO +�+'.. TS:b OTOZ/6T/8 o, c a 00 d08b:b 010Z/61/8 ha % Q fl. M Sb:b 0102/61/8 Et 17 010Z/61/8 I Ob:b OIOZ/61/8 L£:b OIOZ/61/8 b£:b oIOZ/6I/8 Z£:b OIOZ/61/8 6Z:b OTOZ/61/8 in v+'i d 9Z:b 010Z/61/8 Q� 0 3 ai N £Z:b OTOZ/61/8 H C o +° •, OZ t7 OIOZ/6I/8 O. 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C 81:ST OIOZ/61/8 • e-1 +.. 7 F '� 81:51 OIOZ/61/8 Q▪ 0 C dJ 8151OTOZ/61/8 - of Q —o M �c 0 , LIST OIOZ/6T/8 ti 3 L7 c a L1:51 oloz/6T/s J a-+ a ��^ LT:ST OTOZ/61/8 i To y 9151OIOZ/6T/8 MC E E r 9T:ST OIOZ/6t/8 a Q u- i t i -- 9151 0TOZ/6t/8 H C y ST:5T OIOZ/61/8 Q a +'di r ST:ST OTOZ/6T/8 E ^a SISI OIOZ/61/8 b1:SI OTOZ/6t/8 -a ti:ST OIOZ/61/8 CL - E ' b15I0TOZ/61/8 a n £1ST OTOZ/61/8 'a £t:ST OIOZ/61/8 Q. of6a ' ET:SIOTOZ/6t/8 a . ZT:ST OTOZ/61/8 Z1:ST OTOZ/6T/8 Z1:St OTOZ/61/8 > TT:5T OIOZ/6I/8 TT:ST OIOZ/6I/8 � TT:51 OIOZ/6t/8 : �n OT:S1 OIOZ/61/8 • .-i 01:51OTOZ/61/8 0151 OIOZ/61/8 0o 0 0 0 0 0 lD V1 m N a--I Page 1 of 1 Regg, James B (DOA) i From: Regg, James B (DOA) Sent: Thursday, August 19, 2010 10:18 AM To: 'Alan Bailey' ll Cc: 'dan darnell'; 'Randy Baldwin'; 'Amanda Kolker; 'Ray Mann'; 'Robert Kirkman'; Aubert, Winton G (DOA); Brooks, Phoebe L (DOA) Subject: RE: South Elbow Well Initial BOP Test Appears to be a good test; thank you for the charts. PTD should be 2100730 for South Elbow#4 Is system pressure 1200psi or 3000psi (pressure after closure 2800psi)? Previous reports show system pressure as 3000psi. I added low pressure to the test pressure blocks for annular and valves (i.e., 200/750) Jim Regg AOGCC 333 W.7th Avenue,Suite 100 Anchorage,AK 99501 907-793-1236 From: Alan Bailey [mailto:alanbailey@geothermalresourcegroup.com] Sent: Wednesday, August 18, 2010 12:37 PM To: Regg, James B (DOA); Jones, Jeffery B (DOA); Aubert, Winton G (DOA) Cc: 'dan darnell'; 'Randy Baldwin'; 'Amanda Kolker'; 'Ray Mann'; 'Robert Kirkman' Subject: South Elbow Well Initial BOP Test Jim, Dan ran the BOP and FIT tests at Akutan and things appear to have gone smoothly. Charts from the test are attached. We are at our second casing point and preparing to cement. Thanks Alan Bailey Geothermal Resource Group, Inc. alanbailey@geothermalresourcegroup.com 760-341-0186 Office 760-341-9673 Fax 775-304-3253 Cell alan.bailey6l/775-583-4662 Skype www.geothermalresourcegroup.com 1X Untitled 8/20/2010 J � STATE OF ALASKA 01/25/10 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: jim.regaaalaska.gov doa.aoacc.Prudhoe.bay(a)_alaska.qov dJA1V/'T phoebe.brooksta),alaska.gov Contractor: N ntractor Rig No.: 47W DATE: 8/16/10 Rig Rep.: David Griggs Rig Phone: 907-444-1777 Rig Fax: NA Operator: City of Akutan Op. Phone: Op. Fax: NA Rep.: Dan Darnell E-Mail toolpusherdan@yahoo.com Well Name: South Elbow Well#4 PTD# 2100730 Operation: DrIg: X Workover: Explor.: Test: Initial: X Weekly: Bi-Weekly Test Pressure: Rams: Annular: 200/750 Valves: 200/750 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly 0 NA Housekeeping: P Drl. Rig P Lower Kelly 0 NA PTD On Location P Hazard Sec. P Ball Type 0 NA Standing Order Posted P Misc NA Inside BOP 0 NA FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank NA NA Annular Preventer 1 7 1/16 Regar P Pit Level Indicators NA NA #1 Rams 0 NA Flow Indicator NA NA #2 Rams 0 NA Meth Gas Detector P P #3 Rams 0 NA H2S Gas Detector P P #4 Rams 0 NA MS Misc NA NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln. Valves 0 NA Inside Reel valves 0 NA HCR Valves 1 3 1/8 3M P Kill Line Valves 1 1 1/4 P Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 1 3 1/8 3M P Time/Pressure Test Result System Pressure 3000 P CHOKE MANIFOLD: Pressure After Closure 2800 P Quantity Test Result 200 psi Attained 6 P No. Valves 0 NA Full Pressure Attained 40 P Manual Chokes 0 NA Blind Switch Covers: All stations No Hydraulic Chokes 0 NA Nitgn. Bottles (avg): 2400 CH Misc 0 NA ACC Misc 1 NA Test Results Number of Failures: 0 Test Time: 3.0 Hours Repair or replacement of equipment will be made within 0 days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Supervisor at: lim.reggta-�,alaska.gov Remarks: Test went very well. It took 6 seconds to close the anular preventor on the 3-1/2" rods and the pressure dropped 200 psi,lt took the accumulator 40 sec to recharge back up to 3000 psi.lf you have any questions email me @ toolpusherdan@yahoo.com, D. Darnell. A formation integrity test was run 24 HOUR NOTICE GIVEN YES X NO Waived By Jim Regg Date 8/13/10 Time 14:30 Witness Test start 0800 Finish 1100 PLB 01/25/10 2010-0816 BOP NANA LF90 Akutan SouthElbow-4.xls J ^ 0 0 a Y ^ , a) � ^^ 4 • • = EZ:Oi OtOZ/91/8 - oZ:oi O1OZ/91/8 Lt 01 O1OZ/91/8 b1:O1 O1OZ/91/8 11:01 OIOZ/91/8 80:01 O1OZ/91/8 L SO:Oi OtOZ/91/8 N ZO:Oi OIOZ/91/8 H 65:6 O1OZ/91/8 , j • 956 OtOZ/91/8 a ES:6 O1OZ/91/8 O m OS:6 O1OZ/91/8 Tr0( Lt:6 OtOZ/91/8 VV:6 OLOZ/91/8 (13m e-I it:6 O1OZ/91/8 ,b. I 8E:6 O1OZ/91/8 Q SE:6 OIOZ/9t/8 L ZE 6 010?/9i/8 Q N 6Z:6 O10Z/91/8 a-+ Q 9Z:6 O1OZ/91/8 I EZ:6 O1OZ/91/8 OZ:6 O1OZ/91/8 L LT:6 O1OZ/91/8 bt:6 OIOZ/9i/8 tt:6 OIOZ/91/8 806 0102/9i/8 SO:6 O1OZ/91/8 / - Z0:6 OtOZ/91/8 6S:8 010Z/91/8 95:8 OiOZ/9i/8 ES:8 O1OZ/91/8 1 OS:8 O10Z/91/8 1 LV:8 OIOZ/91/8 0 0 0 0 0 0 0 0 0 0 o 0 N 00to Lr)ocr m N O al 0 , t 1, • r- 0 0 cLY 4. L U se d'l O O li 6`�13 (f� 1pe/ l 9 1�, 1Oe dA 6l /'9l Q O��Olp//d) ++ 1 l 6�4.1 �pl0/cP L. 10 '9l/ G LJ d'�• 2' <31. d' Q ! cPl /9l 41 C 4' 6)1 /9l >. N O 9e 10e/9 i se, Olp� 1/ � �l /9 0J 0 ▪ Z ecP p' a c,/ C▪o C 2, Olp�9l/d) E l 9l L. p� 010 /� LL d'1 /9l CO 2 O 61�11p�/9l� Z 3 z cl Ol,9 /& �1 c> 9l M 3 <l• Olp� /� 13 H 8l /'9l • H 9l pl0 /d' E ii 6>02<9l/d) 0. 4.' sl d'l pe/9 01/ lsl, 1pc 610 /9l/ in 0 m in m 0 m Ni o /'l p10et- � l/8 �l0lp�1/ /'9l - sTinITIE SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 Raymond R. Mann PHONE (907)279-1433 FAX (907)276-7542 Program Manager City of Akutan 3380 C Street, Suite 205 Anchorage, AK 99503-3952 Re: Akutan Undefined Geothermal Well, South Elbow Well #4 City of Akutan Permit No: 210-073 Surface Location: 5135' FSL, 1695' FEL, S. 7, T70S, R112W, S.M. Bottomhole Location: 5135' FSL, 1695' FEL, S. 7, T70S, R112W, S.M. Dear Mr. Mann: Enclosed is the approved application for permit to drill the above referenced geothermal exploratory well. This permit application is approved contingent upon the following conditions: 1. Well operations shall be conducted in accordance with 20 AAC 25. 2. Pursuant to 20 AAC 25.035 (h) (1), alternate BOPE is approved. 3. Pursuant to 20 AAC 25.035 (h) (2), the diverter requirement is waived. 4. Pursuant to 20 AAC 25.061 (c), the near surface survey requirement is waived. 5. Pursuant to 20 AAC 25.066 (d) (3), alternate gas detection equipment is approved. At least one methane detector and one H2S detector are required. 6. Test BOPE to 750 psi on a seven-day frequency. 7. Pursuant to 20 AAC 25.020, a Designation of Operator form (Form 10- 411) and accompanying Powers of Attorney must be filed with the Commission within 60 days. Pursuant to 20 AAC 25.071(b)(2), dry cuttings samples must be submitted to the Commission. The preferred sample interval is 10', with a maximum of 30'. A final as-built survey plat showing the location of the well at the surface J referenced to governmental section lines and expressed in Alaska State Plane coordinates referenced to NAD 27 must be filed with the Well Completion or Recompletion Report and Log. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, ort . Se. ount, r. Chair DATED this1.-16y of July, 2010. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA "" 1 V Dot If S12.01c AL .1OIL AND GAS CONSERVATION COMM!, )N JUN 2 9 2010 PERMIT TO DRILL 20 MC 25.005 AltJca tial A Gas Dim commission la.Type of Work: lb.Proposed Well Class: Development-Oil ❑ Service- Winj ❑ Single Zone 0 lc.Speci ifs li is�proposed for. Drill ❑• Redrill ❑ Stratigraphic Test 0 Development-Gas 0 Service-Supply 0 Multiple Zone 0 Coalbed as ')68s Hydrates 0 Re-entry 0 Exploratory E• Service- WAG 0 Service-Disp 0 Geothermal X ' Shale Gas 0 2.Operator Name: 5. Bond: Blanket 0 Single Well 0 11.Well Name and Number. City of Akutan Bond No, 7.-'Z-"6> (4j�3c' /''SouthElbowWell/4 3.Address: 6.Proposed Depth: 12.Field/Pool(s): / / 3380 C Street Suite 205,Anchorage AK 99503-3962 MD: 1500 ft. ND: 1500 ft. t L .!C l r a4 J//_ 4a. Location of Well Governmental Section): 7.Property Designation Le se Number); o:infe r�" Surface: . /35`/3L, /4 '5'`i;27.4., 5,/7/7'705/ l?i tzt',n F .46 tc et-,-.76., . /" �., e, 6 3!) is Top of Productive Horizon: l �,N(, 8.Land Use Permit U 13.App ' ate Spud Date: Subsurface Agreements(CPQ-Attachment C) l 10 /I//O Total Depth: (-6a444.61- 9.Acres in Property: 14:D nce to Nearest Property: At tv 1/4 acre n/a 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 123 feet 15.Distance to Nearest Well Open Surface: x-589064-' y- _932764 Zorn 6 GL Elevation above MSL: 119 feet to Same Pool: Ivo 18.Deviated wells: Kickoff depth: feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: degrees Downhole: 647 Surface: 500 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD ND finclyding stage data) 9.875 6.825 24 K55 Mod BTC 33 0 0 ' 33 33 11.8 cu ft w excess,fie'-frill'4 5.5 4.6 11.2 HWT-4130 MBT-FJ 150 0 0 150 150 15.4 cu fe w/100%excess.Single 01.* Maas conventional 3.78 3.5 7.87 HQ-4130 MBT-FJ 600 0 0 , 600 600.ia:8 J, w,,99% xcess.Single stag nv (j; i 2.98 1.5 3.02 ASTM A-63 NPT T&C 1500 0 0 1500 1500 hang down string 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth ND(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface intermediate Production Liner Perforation Depth MD(ft): Perforation Depth ND(ft): 20. Attachments: Property Plat 0 BOP Sketch 0 Drilling Program 0 Time v.Depth Plot ❑ Shallow Hazard Analysis 0 Diverter Sketch 0 Seabed Report 0 Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Printed Name oRA,Vitt 0D Title fltg_tr NA.M rffee Signature ( „._7-2 . Phone 9 ea. If 2 9. 2.41 3 Date 2 9 -54,A,A,J / 0 E-----).0,1 Commission Use Only Permit to Drill API Number: ermit APPrw i I See cover letter for other Number. �L> ��`�� 50- ���_7 'C y ate: a► requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: [r Other: c q,{tc..11_c_ci go,„,_434..f. outs eft a piro "-(. Samples req'd: Yes_ No❑ Mud log req'd: Yes No❑ 11 H2S//measyres:.JYes['I No❑ Directional svy req'd: Yes-❑ No C 2f&el't i,c `av )l StCAL LL _w , ,:e.,./e.--r-/( W A< !,./. a) ,J J ��( /0 /,./ (PPROVED BY THE COMMISSION DATE: F. 4.' i° �' ,COMMISSIONER 0 • , j 7i•/ts Form 10-401(Revised 7/2009) This permit Is valid for 24 months from the date of approval(20 AAC 25.006(g)) Submit in Duplicate §T Geolhermal Resource Group 0 TAPPING THE EARTH'S ENERGY Bill Rickard, PE Bus:(760)341-0186 P.O. Box 11898 Fax:(760)341-9673 Palm Desert,CA 92255 billrickard@grgi.org Akutan Geothermal Project S o& Elbow Well -Program it* Geothermal Resource Group 0 TAPPING THE EARTH'S ENERGY Bill Rickard, PE Bus:(760)341-0186 P.O. Box 11898 Fax:(760)341-9673 Palm Desert,CA 92255 billrickard@grgi.org c fl' Elbow Well Drilling Program 1. Build location with cellar and site sump to suit core drilling rig. 2. Move in drilling rig and rig up. Notify AOGCC of rig up. 3. Perform a pre-spud safety and operations meeting. 4. Drill 9-7/8" diameter hole to+30 ft from bottom of cellar. Take returns to wellsite reserve pit using cellar pump. 5. Rig up and run 30+ft of 6-5/8" 24 ppf, K55 casing with a Modified Buttress Thread coupling on the top joint. Leave top of conductor(box end) above cellar floor—no more than 6". 6. Cement conductor r 6.1.Run tremie pipe and mix and displace cement into the 9-7/8"x 6-5/8" annulus. 6.2.WOC(wait on cement) until surface grab samples are set. 7. Install Thread-on Riser. 7.1.Line up mixing tub on riser via centrifugal pumps and 2"side outlet valve on lower part of riser. 7.2.Install flow line to mud pit via 3" outlet at top of riser. 8. Pick up P rods and core ahead from to+/-150 ft. 8.1.Notify AOGCC and provide an estimate for completing the section, casing,and BOP testing. 8.2.Follow the mud program while drilling use 8.9 pound per gallon mud and maintaining 9.0 pH. 8.3.Note lost circulation intervals and immediately report lost circulation to the drilling supervisor. 8.4.Be prepared for artesian flow throughout rotary drilled interval. 8.4.1.If artesian flow occurs, mix weighted mud using CaCI and Barite. 8.4.2.If weighting mud is insufficient to kill the well, mix neat cement and spot cement across zone. 8.5.Collect and box 10 foot core samples as per geologist's instructions. 8.6.Run a drift shot with MRT at 100 foot intervals. 9. Run and cement HWT core casing to surface. r 9.1.Circulate and condition hole for casing. 9.2.POH & lay down P core rods. 9.3.Run and cement HWT(4-1/2"OD)core casing to surface. 9.3.1.Install float above 10' shoe joint. 9.3.2.Make up landing joint. Land casing as needed to set top of HWT core casing 1 foot above bottom of cellar. 9.3.3.Cement using 100%excess as per cementing program.Take returns through 2"side outlet on riser. Displace cement and bump plug. / 9.3.4.Take returns through 2"side outlet on riser. 9.3.5.Back-flush cement out of riser bottom through 2" side. 9.3.6.WOC 10. Back off landing joint and pull riser. Clean up threads on riser. Perform top job, if needed. " 11. Make up wellhead assembly. 11.1. Thread on 4"900 wellhead. 11.2. Nipple up 4"900 x 7-1/16"3M DSA. 11.3. Nipple up 6"900 master valve,7-1/16" 3M annular preventer, 1" kill line valve,3-1/8" manual gate valve, 3-1/8"diverter HCR valve, kill and diverter lines. 11.4. Function test annular preventer, kill line,and diverter line valves. 12. Test BOPE to 750 psi. 12.1. Test casing, kill line,and diverter line valves to 750 psi. 12.2. RIH with test plug joint,snub bottom of joint to bottom of annular and test annular preventer to 750 psi. 12.3. While drilling HQ hole,the BOPE must be tested weekly subsequent to the first test. Test the BOPE by landing test plug in crossover and using flared PQ test joint. 13. Pick up HQ rods and wireline core from to+/-600 ft. ' 13.1. Perform formation integrity test. 13.1.1. Drill out float and shoe track and clean out cement. 13.1.2. Drill ahead making 0 feet of new hole. 13.1.3. Apply surface pressure to annulus to an equivalent 0.625 psi(12.0 ppg)gradient. - 13.1.3.1. Apply pressure at 0.1 bbl/1 minute increments. 13.2. Notify AOGCC and provide an estimate for completing the section,casing,and BOP testing. 13.3. Follow the mud program while drilling. 2 13.4. Monitor flowline temperatures constantly. 13.5. Note lost circulation intervals and immediately report lost circulation to the drilling supervisor. Maintain water on the backside to prevent flashing. 13.6. Be prepared for artesian flow throughout rotary drilled interval. 13.6.1. If artesian flow occurs, mix weighted mud using CaCI and Barite. 13.6.2. If weighting mud is insufficient to kill the well, mix neat cement and spot cement across zone 13.7. Collect and box 10 foot core samples as per geologist's instructions. 13.8. Run a drift shot and MRT at 100 foot intervals. 14. Run and cement HQ(3-1/2") core casing to surface. 14.1. Circulate and condition hole for casing. 14.2. POH & lay down P core rods. 14.3. Run and cement HQ core rods. 14.3.1. Install float above 10'shoe joint. 14.3.2. Make up landing joint. Land casing as needed to set top of HQ core below wellhead flange. 14.3.3. Cement using 100%excess as per cementing program.Take returns through diverter liner. Displace cement and bump plug. V- 14.3.4. Back-flush cement out of wellhead riser bottom through diverter line. 14.3.5. WOC 15. Back off of landing joint and nipple down wellhead assembly. 15.1. If a top job is needed, break off the thread-on wellhead and make landing joint back up. Mix a / non-accelerated tail slurry and pour slowly down one side of the annulus, allowing any mud or contaminated cement to exit the other side. Once results are achieved, break off the landing joint and make the thread on wellhead back up. 16. Make up the wellhead assembly and function test the annular preventer and side outlet valves. 17. Test BOPE to 750 psi. 17.1. Test casing, kill line, and diverter line valves to 750 psi. 17.2. RIH with test plug joint,snub bottom of joint to bottom of annular and test annular preventer to 750 psi. 17.3. While drilling NQ hole,the BOPE must be tested weekly subsequent to the first test. Test the BOPE by landing test plug in crossover and using flared PQ test joint. 18. Make up NQ rods and wireline core+/-1500 ft. • 18.1. Perform formation integrity test. 3 18.1.1. Drill out float and shoe track and clean out cement. 18.1.2. Drill ahead making 20 feet of new hole. 18.1.3. Apply surface pressure to annulus up to an equivalent 0.625 psi (12.0 ppg)gradient. 18.1.3.1. Apply pressure at 0.1 bbl/1 minute increments. 18.2. Follow the mud program while drilling. 18.3. Monitor flowline temperatures constantly. 18.4. Note lost circulation intervals and immediately report lost circulation to the drilling supervisor. Maintain water on the backside to prevent flashing. / 18.5. Be prepared for artesian flow throughout rotary drilled interval. 18.5.1. If artesian flow occurs, mix weighted mud using CaCI and Barite. 18.5.2. If weighting mud is insufficient to kill the well, mix neat cement and spot cement across zone. 18.6. Collect and box 10 foot core samples as per geologist's instructions. 18.7. Run a drift shot and MRT at 100 foot intervals. / , 18.8. If bottom hole temperatures in excessf�5deg F are encountered, it will be necessary to cement the NQ rod in place and reduce to BQ. 18.9. If torque or wellbore stability becomes a problem, reduce to BQ. 19. Upon reaching TD,follow Pressure/Temperature Logging Procedure. 20. Run tubing into well and hang from the wellhead. 20.1. RIH with tubing to near bottom. 20.2. Make up a landing joint and hang the tubing in the mast. 20.3. Kill the well thoroughly using cool water or weighted mud. 20.4. Unbolt the crossover from the wellhead and lift to get access to the tubing joint. 20.5. Slip a spade plate underneath the tubing collar and land tubing on the plate. Back off landing joint. 20.6. Make up tubing hanger flange and land on the wellhead flange. 20.7. Nipple up the flanges and close the top valve. 21. Release rig. 4 Akutan Test Well Project Cement Volumes—Hot Springs Well Drawn by A.Bailey,GRGI 6/2/2010—Not To Scale 6-5/8" Conductor Premium II 13.5 ppg cement w/30% Silica Flour and 3% CACI • 11.176 gallons water/sack r • Yield 2.16 cu ft/sack 9.875 in f I f No Total: 20%Excess /;' Z•vo bbl . • 5 sacks cement, 7,V70 -�.1C 33 ft • 140 lbs silica flour • 14 lbs CaCI, 6.625 in Csg • 56 gallons of water 24.00 Ibm/ft _ 33 ft �, 4 None �/ 44.5" Casing 2. • Bbl iiii 5.500 in j / Premium II 13.5 ppg cement w/30 % Silica Flour and 100%Excess /%'. / 2% CaCI 150 ft /.! .' • 11.144 gallons water/sack / i; ' • Yield 2.15 cu ft/sack 4.500 in Csg / / , ./`% Tot I ^ 9.50 Ibm/ft 1 r • sacks cement ,` 150 ft ! ! / • 200 lbs silica flour /, 'f • 13 lbs CaCI !, /.. r • 78 gallons of water / , 3.500 in CT �' / 3.5" Casing 9.65Ibm/ft / / 600 ft /, f Premium II 13.5 ppg cement w/30% Silica Flour and /- / o 1� 0.75/o retardant 3.780 in V / •. bbl • 11.068 gallons water/sack 100%Excess / • Yield 2.13 cu ft/sack 600 ft Tot Z 771 41-1- /.. / • 6,sacks cement • 170 lbs silica flour // • 4.25 lbs retardant (Halad 413 equivalent) • 66 gallons of water litAkutan Test Well Project Elbow Well 2 Drawn by A.Bailey,GRGI 5/25/2010—Not To Scale 3M Casing Head Flange with/ 3M Tubing Hanger and 1-'/2" 1000 psi Steam Service Valve /:// 5-'/2 Oversize PQ Core to 150 "/\ � � 4-'/2" HWT 11.2#/ft 4130 Butt Casing to 150' Burst Pressure — Box Shoulder = 2656 si p/ \\.\ , Burst Pressure — Midbody = 6218 psi 4 \ \ Collapse Pressure — Midbody = 6560 psi \ \ (316 deg F Max temp at shoe) \\ \\ \ 3.78" HQ Core to 600' 3-'/2" HQ 7.67 #/ft 4130 Butt Casing to 600' Burst Pressure — Box Shoulder = 4365 psi Burst Pressure — Midbody = 6501 psi Collapse Pressure — Midbody = 5788 psi (421 deg F Max temp at shoe) 1-W Tubing hung down from surface 2.98" NQ Core to — 1500' Akutan Test Wells lit Cellar Configuration Drawn by A.Bailey,GRGI 5/25/2010—Not To Scale .• . � Rig Floor I i CflN J o ZD 6-5/8" x 14" riser I > 2 0 7-1/16 3M Lo Annular Preventer jr) co co co ,-- r--: N • I I ' v (iA) v > N 00 0 W 6" 900 Exp. Gate <---- 0_ C Valve w/GT Trim m 1 > _ I X X a) N 127 1 'r — — I I CO 3 -- W • T Fri \ CD fD 0O \ 00 >y W I I Cellar - 72" Diameter . . • is((4.' Job Recommendation Akutan Test Well Cementing Materials Test Well 9 1 Volume Calculations and Slurry Properties 6-5/8"Conductor VOLUMES 9-7/8"X 6-5/8" 33 FT X 0.29247 FT3/FT = 9.652 FT3 X 20% = 11.58 FT3 Total Gallons 86.6 GALLONS Total BBLS 2.06 BBLS 12 BAGS TC GEOLITE+3%CaCl2 6-5/8"Cement Slurry Density: 13.5 lb/gal Yield: 1 ft3/BAG Water: 4.16 gal/BAG Slurry Volume: 89.8 GALLONS Slurry Volume: 12.0 FT3 Slurry Volume: 2.1 BBLS Mix Water Required: 49.9 GALLONS 4-1/2"Casing VOLUMES 6-5/8"X 4-1/2" 33 FT X 0.0808 FT3/FT = 2.666 FT3 X 0% = 2.67 FT3 5-1/2"X 4-1/2" 117 FT X 0.0545 FT3/FT = 6.377 FT3 X 100% = 12.75 FT3 Total Cubic Feet 15.4 FT3 e' Total Gallons 115.3 GALLONS Total 6815 2.75 BBLS 16 BAGS TC GEOLITE+2%CaCl2 4-1/2"Cement Slurry Density: 13.5 lb/gal Yield: 1 ft3/BAG Water: 4.16 gal/BAG Slurry Volume: 119.7 GALLONS Slurry Volume: 16.0 FT3 Slurry Volume: 2.8 BBLS Mix Water Required: 66.6 GALLONS 3-1/2"Coiled Tubing VOLUMES 4-1/2"X 3-1/2" 150 FT X 0.024423 FT3/FT = 3.663 FT3 X 0% = 3.66 FT3 3.780"X 3-1/2" 600 FT X 0.011152 FT3/FT = 6.691 FT3 X 100% = 1 8 FT3 Total Cubic Feet 17.00 ff3 Total Gallons 11.5 GALLONS Total BBLS 3.04 BBLS 18 BAGS TC GEOLITE+defoamer+retarder 1%to be determined from lab tests) 3.5"CT Cement Slurry Density: 13.5 Ib/gal Yield: 1 ft3/BAG Water: 4.16 gal/BAG Slurry Volume: 134.7 GALLONS Slurry Volume: 18.0 FT3 Slurry Volume: 3.2 BBLS Mix Water Required: 74.9 GALLONS 2.75" NQ ROD VOLUMES 2.99"X 2.75" 750 FT X 0.007513 FT3/FT = 5.635 FT3 X 0% = 5.63 FT3 2.98"X 2.75" 750 FT X 0.011152 FT3/FT = 8.364 FT3 X 0% = 8.36 FT3 Total Cubic Feet 14.0 FT3 Total Gallons 104.7 GALLONS Total BBLS 2.49 BELS 14 BAGS TC GEOLITE+defoamer+retarder 1%to be determined from lab tests) 2.75"NQ Cement Slurry Density: 13.5 lb/gal Yield: 1 ft3/BAG Water: 4.16 gal/BAG Slurry Volume: 104.7 GALLONS Slurry Volume: 14.0 FT3 Slurry Volume: 2.5 BELS Mix Water Required: 58.2 GALLONS BoartLongyear Energy Products Group OPERATOR City of Akutan WELL NAME Hot Springs (1,500' TD) LOCATION Akutan, AK SUR. CSG. 6 5/8" @ 30'; 4'/2" @ 200' INT. CSG. 3 1/2" @ 600' TUBING 1 '/2" hung to 1,500' RECOMMENDED MUD PROPERTIES DEPTH WEIGHT VISCOSITY FILTRATE FEET PPG. SEC. ML MUD TREATMENT 0'- 200' 8.5-9.2* 38-50 <15 Utilize Freshwater Bentonite system to drill surface holes for setting surface casing; Quik Gel/X-Hi-Yield Gel for viscosity and good hole cleaning, Soda Ash for pH 9-10. Note possible artesian flow through this interval; utilize Calcium Chloride and Barite for control as needed. Run and cement 4 '/2" (H rod) casing to 200'. 200'- 8.5-9.0* 32-38 5-15 Mix Gel/polymer coring fluid and continuously 600' core (HQ) from 200' to 750' with HQ rod. Maintain 8-20ppb Bentonite (always add Gel first), with .5-1.0 #/1,000 gallons EZ Mud Gold and .5-1.0 ppb Pac LV. Add .5-.75 ppb Soda Ash for pH 9-10. Maintain viscosity at 32-38 sec/qt with fresh Gel, EZ Mud Gold and Polyvis as needed; this will also provide lubricity for coring. TORKease may be utilized for additional lubricity/rod chatter; Desco to thin if needed, and Defoamer if needed. IF artesian conditions are encountered, consider increasing fluid density with Calcium Chloride; if whole mud losses are encountered, keep a fluid level by pumping coring fluid and water down the annulus. At 600', cement 3 '/2" core rod or casing. 600'- 8.5-9.0* 32-38 5-15 Continue coring (NQ) with the Gel/EZ Mud Gold 1,500' system as above, using Pac LV and Polyvis as needed for fluid loss and viscosity. Core ahead to projected TD of 1,500'. At TD, perform any temperature logging, kill the well and run 1 '/2" tubing. REMARKS: Maintain minimum mud weights possible (utilizing shaker, hydrocyclones). II. Artesian Conditions —Artesian conditions are possible during this project. Calcium Chloride can be premixed if desired, and stored for potential use. Barite or Calcium Chloride can both be mixed into the coring fluid. III. Zinc Carbonate or Zinc Oxide should be maintained on location, in case of the presence of hydrogen sulfide. IV. Implement good coring practices, and monitor hole conditions closely to identify appropriate coring fluid properties. Boart Longyear personnel have carefully prepared this proposal to the best of our knowledge of the area and formations to be drilled,and the operations and concerns of all involved parties. No representation or warranty is made by Boart Longyear or our representatives and/or agents,as to its correctness or completeness,and no liability is assumed for any damages resulting from the use or application of the same. By acceptance of this proposal,Operator/Owner and/or representatives of the Operator/Owner, agree to hold Boart Longyear and/or any Boart Longyear employees/representatives harmless,and to indemnify Boart Longyear against all claims resulting from the use or application of this proposal. LA Basin Ventura San Diego Oregon SF Bay Area (800)782-3222 (805)653-7975 (858)566-4603 (661)212-1223 (800)782-3222 0 Geothermal Resource Group TAPPING THE EARTH'S ENERGY Bill Rickard, PE Bus: (760)341-0186 P.O.Box 11898 Fax:(760)341-9673 Palm Desert,CA 92255 billrickard@grgi.org June 13, 2010 Pressure/Temperature Logging Procedure 1. After retrieving the core at hole TD, circulate the hole for a minimum of 1 hour. 1.1.Reciprocate pipe frequently while circulating. 2. Make a wiper trip from TD to the casing shoe. RIH to TD. 3. Circulate and condition hole for logs. 3.1.Carefully note the time at which circulation begins. 3.2.Thin mud back with water to around 8.6 pounds per gallon. - 3.2.1.Circulate until the mud properties are the same going in and coming out. 3.2.2. If there is no circulation, pump a full hole volume of 8.6 ppg mud. 3.3.Circulate until a stable flow line temperature has been reached. 3.4.Reciprocate pipe frequently while circulating. 3.5.Carefully note the time at which circulation ends. 4. Pull out of hole. 5. Make up wireline lubricator, FOSV,or stab in with circulating pin. DO NOT CIRCULATE UNLESS NEEDED FOR WELL CONTROL. 6. Prepare Pressure/Temperature tool and synchronize with P/T laptop. 7. Make up 0-650 deg F Pressure/Temperature tool in accordance with PPS logging procedure. Use wireline lubricator during the log run. 8. Begin Log Run#1. This run should begin 6-8 hours after circulation has ended. 8.1.Note exact time that log run begins, and exact time at each station while running log. 8.2.Run in hole slow, making stops on 20 foot stations. Time on station will be established by PPS engineer. , 8.3.Make additional stops at points selected by geologist. 8.4.Do not attempt to force tool past any tight spots. If tools sets down and won't proceed, RIH and clean out tight spots. After cleaning out tight spots, return to Step 3 and repeat the entire process. 9. Download and examine data at end of run. 10. Begin Log Run#2. This log run may begin at any time after completing Log Run#1. 10.1. Note exact time that log run begins,and exact time at each station while running log. 10.2. Stations and time spent on station should be duplicated from Log Run#1 10.3. Do not attempt to force tool past any tight spots. Examine data—if tool sets down below any points of interest,the log run may be considered complete. Otherwise, it may be necessary to clean out hole and repeat from Step 3. Sample Data Sheet Station Log Run 1 Log Run 2 Delta Depth Arrive Depart Time on Time Temp Arrive Depart Time Time Temp Temp Station since Last on since Last Circulated Station Circulated Flow Testing and Sampling 1. After completing Pressure/Temperature Logging to the satisfaction of the wellsite geologist, RIH to bottom with bit. 2. Circulate fresh water down pipe, reciprocating pipe constantly. 2.1.If the well will circulate, circulate fresh water until returns have reached a mud weight of 8.5 or less. 2.2.If circulation has been lost, pump 2 full hole volumes. 3. Pull out of hole to the casing shoe and run wireline float to determine the fluid level. Run FOSV's on core rod while tripping out. 4. Run the wireline float using the wireline lubricator. 5. Once the fluid level has been determined, pull out of hole to a point 200 feet below the top of the fluid level. 6. Rig circulating pin,flow line,and blooie line to take returns through core rod. 7. Rig up compressor. 8. Reverse fluid out of the wellbore 8.1.Close the annular preventer and 4-1/16"flowline valve. Maintain a copious amount of cold water on the annular preventer constantly while performing this task. 8.2.Apply air to the annulus via the 3-1/8"side outlet valve. Do not exceed 150 psi. If 150 psi is not sufficient to lift well, bleed of pressure and pull out of the hole to a shallower depth below the water level. 9. If well blows dry, RIH 150'and blow down again. Run FOSV's on core rod while running in hole. 10. Once flow rate and temperature appear to have stabilized, bypass the compressor and close the 3-1/8"side outlet to determine if the well will flow on its own. If not,open the valve and resume air lifting. 11. Continue flow testing for at least one hour after pressure and temperature have stabilized. 12. Obtain water samples via the sampling port after the fluid has cleared up—at points 2/3rds through the test and prior to ending the test. 13. Begin killing well. 13.1. If air is on, bypass air and power down compressor. 13.2. Pump fresh water down the annulus. Observe returns at blooie line. 13.3. If killing the annulus does not also kill the drill rod,close the blooie line valve and disconnect the blooie line from the flow line. Line up pump and pump fresh water down drill rod. 14. Continue pumping down the annulus while pulling out of the hole. Sample Data Sheet Annular Flow Line Blooie Line Time Air Pressure (Wellhead) Pressure Pressure Pressure Note: If the well cannot be airlifted, it will be necessary to obtain a water sample by bailing the hole. Bailing Procedure 1. Allow wellbore fluids to stratify for 6-12 hours. 2. RIH with slowly with bail on wireline to desired sampling interval as directed by geologist. 3. Work bail repeatedly and vigorously up and down across selected interval for several minutes. 2 4. Pull out of hole with bail. Injection Testing 1. Line up rig pumps to fresh water source. 2. Rig up wireline lubricator and close annular preventer. 3. RIH with PT tool to 100 feet below top of static water level. 4. Perform a 3 step injection test by pumping cold water through 1"side outlet. 4.1.Pump at approximately 25%of the top rate of the mud pump for 20 minutes or until injection pressure has stabilized. Do not apply more than 100 psi at wellhead. Record pump rate,stroke rate, and injection pressure. 4.2.Increase pump rate. Do not exceed more than 50%of the top pump rate or more than 150 psi. Inject for 20 minutes or until injection pressure has stabilized. Record pump rate,stroke rate,and injection pressure. 4.3.Increase Pump rate. Do not exceed more than 75%of the top pump rate or more than 200 psi. Inject for 20 minutes or until injection pressure has stabilized. Record pump rate,stroke rate,and injection pressure. 5. After completing injection test,allow well to recover for 4 hours. Pull PT tool from hole, rig down lubricator and prepare to run tubing. 3 -4"— o as � E > o 1- 2 ca cu N m (i)CD � z a CO — c o O Z Qm Q t L N N ' .0 0 0 O O m 0 Q CU 79 E v- r CCC 7 N 0 I(n ..0 > _c U) Q 1- _ / m C /•� > N f4 �/ N le 1 co = O II 12N < Q 0 E J a) I- 0) O C a) Q > CES el- O CO Co m z .o I • co U a c CO� O 0 M — aO o r. L 4. U) O c .� ... O cL. a, .0 oU D X N co CL CL Z Z co a M � L CI_ CD O 0 as .0 c r/ o Q V) L Omem O a) Q MZ ______ ■ a) L as EMU lit Akutan Drilling 2010 Sample Bailer Drawn by A.Bailey,GRGI 5/15/2010—Not To Scale • li1-1/2" Coupling XO to wire rope socket O O Top Strainer– 1-1/2" X 8" Nipple with holes drilled ■ 1-1/2" Coupling " Check Valve – spring cut to tvvil Top 1-1/2reduce plunger pressure III 1-W Coupling Sample Chamber- 1-'/2" X 60" Nipple ■ 1-'/2" Coupling Bottom 1-'/2" Check Valve – spring cut to mril reduce plunger pressure • —Bottom Strainer– 1-1/2" X 8" Nipple with holes drilled— . 1-'/2" Coupling _Sinker Bar, 1-'/2" Sch 40, 5 feet long and filled with sand. Epoxy plug at top . End Cap – Rounded to a Bullnose CITY OF AKUTAN,ALASKA WELLSITE GEOLOGY PROGRAM FOR GEOTHERMAL TEST WELLS Driller's responsibilities The driller's helper will box and label core, and stack the boxes on a pallet. Don't let them skimp on boxes—"one barrel, one box." It is important to emphasize that they let the core drain really well before boxing. Otherwise, the box will be full of polymer. The driller (or helper) will prepare daily drilling logs, core reports, weekly situation reports, serious incident reports, as required, and end of well reports. Rate of penetration and mud returns will be obtained from the driller. The driller will need to log drilling times on his worksheet, and note intervals where there are "drilling breaks". He will also need to note if he is losing (or gaining) fluid. These numbers will be entered manually into the logging software by the wellsite geologist. The driller will take drift measurements at 100 foot intervals while drilling to determine deviation from true vertical. At the same time, the driller will run an MRT to take bottom hole temperature. The driller will note the MRT reading on his tour report and the geologist will log the bottom hole temperature from the MRT on the mud log. Core Logging Procedures 1. Wipe the slime off the core (polymer and mud, etc.) using a bucket of clean water and sponges/towels. Can use the provided spray nozzle and water hose. But don't get too energetic and scub the core itself away! 2. A box of core will read just like a book—left to right and top to bottom. On each cut of core, put a red line on top of each section and a black line on bottom.This orients each core section relative to top and bottom. 3. Mark a section number—if broken into 12 pieces, mark 1-12. Include any pieces that appear to be ready to fall apart. 4. Do gross description. If need to see a fresh surface, whack w/rock hammer. Note the following: 4.2 Rock Type. 4.3 Color. Use a GSA color chart. 4.4 Texture. 4.5 Hardness and Induration. A trick to determining induration is to hit the core with a hammer. Highly indurated or silicified rock will "ring" and poorly indurated or CITY OF AKUTAN,ALASKA WELLSITE GEOLOGY PROGRAM FOR GEOTHERMAL TEST WELLS argillic altered rock will "thud." Everything in between is more or less a judgment call. 4.6 Fractures, veining, vugs and other physical features. Use a protractor for a rough angle. 4.7 Hydrothermal alteration. Describe suite (argillic, propylitic, etc.) 4.8 Hydrothermal mineralization. 4.9 Contact or contact zone, and whatever length interval it's over (use a tape measure) 5. Fill out placard with the following information: 5.2 Core Box Number; 5.3 Depth from and to; 5.4 Estimated Percent of Recovery. (I print out batches of these on blank 3x5 index cards and fill in the blanks.) After taking the photo, tuck the card underneath a piece of the core. This will help to identify the core if the lid to the box should be lost. 6. Take a high-resolution digital photo of the core box: 6.2 Pay attention to color. Be consistent—always photo either in natural light (set light balance) or copper photo lights—don't try to photograph in incandescent light. Run an egg timer and set it for an hour, set light balance over course of the day. Photograph in oblique light so no glare. Kodak color separation chart. Set white balance. 6.3 Make sure it's from the same fixed distance each time (use tripod w/ piece of string to measure distance) 6.4 Include placard as well as core box 6.5 Photograph anything else significant. 6.6 Photograph the chart each time the white balance is reset and try to include the color chart in each photograph. 7. Transpose descriptive data from worksheet into LogPlot 8. Enter other data (rate of penetration, PT info, circulation information, etc... into LogPlot. 9. Maintain a 10 foot sample chip set for Alaska Oil and Gas. • CITY OF AKUTAN,ALASKA WELLSITE GEOLOGY PROGRAM FOR GEOTHERMAL TEST WELLS Supplies: Core Logging - Bucket of clean water - Sponges and towels - Water hose w/spray nozzle - Black and red permanent markers - GSA color chart - Rock hammer - Hand lens and/or magnifying glass - Blank index cards - Pre-printed index cards ("placards") w/ info given above - Digital camera and tripod - Kodak color index - Egg timer - Copper photo lights? - Laptop w/ LogPlot software CITY OF AKUTAN,ALASKA WELLSITE GEOLOGY PROGRAM FOR GEOTHERMAL TEST WELLS 6$ Akutan Test Well Projed MAO*TAul2reereeece'rN // USB DATA RECORDER —Type T.J or K Therm000uple— —SY'Thermanetl-Threaded— _ _ 15'Couplmg— Schematic of Flow Line Data Recorder O a 7-1 •L V lel N _ E - O J U W I- N W F- J CQ cc Q Y = a 0 J W z N Q H 2 U Q s 00 >- i- i a T • C Q C O- G d N W GJ Q T H GJ O O H t Q a) E O L LL Akutan Account Codes 99.01 Mob/Demob 99.02 Rig Footage 99.03 Rig Hourly 99.04 Rig and Camp Fuel 99.05 Location Cost 99.06 Communications 99.07 Camp Services 99.11 Drilling Supervision 99.12 Drilling Engineering 99.13 Geology 99.14 Logistics 99.15 Roustabouts 99.16 Travel Expense 99.17 Vehicles 99.21 Helicopter Daily 99.22 Helicopter Fly Time 99.23 Helicopter Fuel 99.31 Conductor & Casing 99.32 Cement 99.33 Bits & Tools 99.34 Drilling Fluids 99.35 BOPE 99.36 Wellhead & Tubing 99.37 Small Parts & Supplies 99.41 Rental Equipment 99.42 Drift & Directional Tools 99.43 Logging & Well Testing 99.44 Other Services 99.45 Shipping rEplacEmEnt parts industriEs, inc. CALL 800-221 -9723 or 818-882-8611 • FAX 818-882-7028 E-MAIL: techsupport@rpiparts.com • WEBSITE: www.rpiparts.com "The Alternate Source"' RPT 113 MAXIMUM REGISTERING THERMOMETER INSTRUCTIONS This thermometer registers the highest temperature it has been exposed to and holds that temperature indi- cation until reset. This feature works on the principle of a constricted capillary; on heating, the expansion of the mercury within the bulb forces the mercury col- umn through the constriction. The constriction pre- vents the mercury column from retreating under the influence of gravity or mild vibration. Retraction of READ COLUMN the column is accomplished by `shaking' the ther- HERE FOR MAXI• mometer, much like one would a fever thermometer, MUM TEMPERA- thus generating centrifugal force and forcing the mer- TURE —o- cury column back through the constriction. Do not be concerned about the apparent separation of the mercury column below the constriction. This is a normal condition while the indication is above ambi- ent temperature, and will not affect the accuracy of the indication. The mercury will rejoin after shaking down to ambient temperature. IMPORTANT: The thermometer should be reset prior to each use as described above. Be sure to continue shaking until the column registers approximately ambient room temperature. Place the thermometer into the environment you wish to measure. The ther- mometer should be allowed to remain exposed to the temperature you wish to measure for at least five min- utes, and ALLOWED TO COOL TO AMBIENT TEM- PERATURE BEFORE IT IS READ. READ IN AN DO NOT BE CON- UPRIGHT POSITION AND ONLY AFTER IT HAS CERNED ABOUT SEPARATIONS COOLED TO AMBIENT TEMPERATURE OR YOU HERE WILL OBTAIN A FALSELY HIGH READING. O /1\H REV (3/00) _ \ > CD ƒ\ /kE k \ § s g ; aJ] ® - 8 ° - U - Ea 4-0 > 00 c 03 ° £ 4. m ® [cell E 2o0 - o / cc co i-7 Na a)_es) c tea0) / § % c Ca 0 / \\) _ \ { - 2 0 J / «\ [m O ƒ0 En } // o I � � ' co 00- { 0 \ 0 � o 0 0 m ) # 00 xo {6 2 ® - > k ) fC 0 — ƒ dee co — 0 0 M _ \ / Z - ] )0 Q. { 2 0 CC a a 0 CO 14.1 3 13 k \k k ) { `2 � 0- o _ {e - $ ® 2R\Cf — \) — a§ f t8 00 00 »o »o «;@ o� c £ E• e . 00 ® ] @2 Ce 0 c # cn c� \ _ � � (k\ _ i22 { 2� X27 f Conditions of Approval City of Akutan South Elbow Well 4 (PTD 210-073) 1. Well operations shall be conducted in accordance with 20 AAC 25. 2. Pursuant to 20 AAC 25.035 (h) (1), alternate BOPE is approved. 3. Pursuant to 20 AAC 25.035 (h) (2), the diverter requirement is waived. 4. Pursuant to 20 AAC 25.061 (c), the near surface survey requirement is waived. 5. Pursuant to 20 AAC 25.066 (d) (3), alternate gas detection equipment is ap- proved. At least one methane detector and one H2S detector are required. 6. Test BOPE to 750 psi on a seven-day frequency. _ c1 T•' O i), ti \ t \% . ifl li .►. �, sY w , 't,,; •:.r - :�t C. * i 0 i.,_�\�j E } ..b , SQ-----.... ___,,,--> • ,....,_ ,--', Y.' 1 ..., , (.,, „. ..., a. r 1� . y . — i 1 Q 1 .1 / 4\....._\ Vi/ o Co A �� �-/ 1 fir, - L @ 2 ( a m -7- _ \ — / / )i1' '' ., a , . .- tia-._-_.? .4N' ::-1' O ! O 7( , ,_,..i_. N pi ZV � --- � . I ) J . •- ---_ � � N N • . )' 0.„.1i.„).;,/ _.- ( , in �«r- / (NI ' d• 1 y C S ._�T ---/ 1'�"$�7d I/ O O Q a 1 ` _ }ti,� �1% I p ....., - . :..._..___:__ ,....... / I , ,_ ,, , . , ci-f... a s co ( 7 �co �,,•I / r .) 1,.. 11°. •. J W �.1 ! % r: N n• N N r` t,, ��`/ `a `1 s N 4-- r.- to, LL , of t0 O. a yk, I 1 l > I M, m . 111 /+ia1 1 N Q Q \. '','"/:/�,," a1 ,\� ( x N O M r !fi, Lfl IAf �i \' � l '; rel m . .t. 1I - 2 M N- • .ti" H } N .j1 0.1 /.ice '— a/`t'1. p 3 o ,, , \, a' ti 3 e4 111 ` --../ -(: _ 1 )1 IA ' � 0 it 4 ' - : , - yt ' ' J --ti ! L LL LL 3'. _i_t_... - •fit) -5 \,,,,A, isn' % .'+4P +•.+: %' � LT, 12 LL .> ---. .• - rte...-. $ ( i\if f___;, ' ':',':',,- �lk);$ oc . u E r. `; ( i „,, Lam' 1.,..,.. .,, :....,,......,,,\,,,:„ , ( 1 , i , .‘,./;;.., _, ,,----,,., 1 ,...,.,, 0 .; ,p a) ./r _/ ,�(fr'.., J I�//ri ��'� _ �t al 1 'p(,, C Ln W ! co to aCI a3 �t0,,,..- j y* '' i _o � ( E N N ` �,u •— .r r G e, • ----t..„,1 r \----.--- ,..,' ,,,,,,,, it ..4.0,,,-.2 .., le' L'..i0- .. a) 1 . t„ ' l I I t , r ''/4 \--.1.11 •-,rl /' N o E I- cu QJ r- o W a� ( � � � cu cmco ' Dov a ' < 0 vi "fit 1 AOGCC South Elbow Well 4 1 July 2010 INPUT OUTPUT Geographic,NAD83 State Plane,NAD27 5008-Alaska 8,U.S.Feet Accuracies of conversions from NAD 83 to NAD 27 are typically 12 to 18 cm. South Elbow Well 4 1/1 Latitude: 54.13753 NorthinglY: 50558.607 Longitude: 165.87828 Easting/X: 526521.329 Convergence: 0 06 00.87823 Scale Factor: 0.999900802 Datum Shift(m.): Delta Lat.=96.664,Delta Lon=-128.859 (.1 1 J A•gY Z,c3Y�C�_ '- /V ADL '7 6—'/3S5 X S zl z3,5— / 'W /x`15 t,9 �L�_� .• 5 . 7� 112 Jam, 5.m, Remark: Conversion from NAD 83 lat/long to NAD 27 ASP Zone 8 Corpscon v6.0.1,U.S.Army Corps of Engineers Davies, Stephen F (DOA) From: Robert Kirkman [REKirkman@rmabs.com] Sent: Thursday, July 01, 2010 9:38 AM To: Davies, Stephen F (DOA) Cc: raymann@rmabs.com Subject: RE: Coordinates Needed Attachments: GeothermalVicinityMapUpdate2_lowres(2).pdf Hi Steve, Coordinates as requested projected in Lat/Long: Well 4 N 54.13753 W 165.87828 Well 3 N 54.14333 W165.87390 I did not come up with any difference when I reset the coordinate reference from NAD 83 To WGS 84. The main difference is between NAD 27 and NAD 83/WGS 84. I attached a geospatial map with the wells located on it. If you download a free copy of terra tools, you can obtain dynamic lat/long readings when you pan across the map. Call if you have any questions. Bob Robert Kirkman Technical Services Manager RMA Consulting Group 221 E. 7th Avenue, No. 101B Anchorage, AK 99501 (360) 259 9570 --representing-- City of Akutan 3380 C Street, Suite 205 Anchorage, AK 99503-3952 From: Davies, Stephen F(DOA) [mailto:steve.davies@alaska.gov] Sent: Wednesday, June 30, 2010 4:15 PM To: REKirkman@rmabs.com Subject: Coordinates Needed Bob, 1 Thanks for your help. I could use the lat/long coordinates for North Elbow Well 3 and South Elbow Well 4 referenced to both WGS 84 and NAD 83 if possible. With two separate coordinate systems, I'm sure that I can make the conversion I need and likely won't have to bug you again. Steve Davies Sr. Petroleum Geologist AOGCC 907-793-1224 2 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME !/2- MC-7 /0-e/7 PTD# 7-5 Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: c41/,( POOL: al - 1�1 (;/2-_)-/-/e Y'12'(4 ( Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. 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