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'O1 E ® 0 0 V U aci o � © >- (E I E oo 414( c 1 E ° O to J ° 00 ° H E Cr illJ 0 y 1 O G p Z m RI CO c CD ': c am) E �I-.- z co c o 1 -- E V • m 2 t O O c• w " '1 w� m (0 CO cn N m cA v a°)i c G O O c — @ Q` • -o m Q O Z E m OT O ` m _ CI E 0 o 2 a co z „q Na) U C ® • co O E p p O c 5, 3-5 ill o m o ~ a a' v co o O 3 d m r W _ O N a c U c y U) S E m - m Z a m Ihi 10 Z� 0 N i 1 M H m d Q 0 o 2 1I c c U E ° E V O ° ' ° E vo ° mHE m E E o 0 - LLo cm 0 Q Zr) 3 ? 0 a 0 0 U I o 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 +1-3-5 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 1 1.11.....I.P......................MIPRII.T.M...111.Tewn..........m',.......T.M..............M.IMPIAILINI ...11........MORRRMMMIMOPIIMPIRJ APPENDIX SPECIFICATIONS Altimeter: Accuracy;4-/-10 feet*.resolution;Ili. APPENDIX 'Satjccl to proper u cr calibration. Specifications Power Source: Two 1.5 volt AA batteries.USB Data Cable, Physical 12 Volt DC Adapter Cable or up to 26 Volt DC Site: 6.1"11 x 2.4"W x 1.3"D external power N eight:7.5 ounces(213 g)w/batteries installed. Battery Lite: Up to 18 hours(typical use) Display:1.5"W x 2.2"H,256-color.olor,high resolution, .Alkaline butteries lose a significant amount of them capacity as the transreftective(160 x 240 pixels)with backlighting. temperature decreae t sten ite use of screen backlighting.electronic Case: Rugged,fully gasketed,water resistant.IEC-529.I PX7 compass.,and audible tame significantly reduce haters tiff. Temp Range:5 to 158T(-I5 to 70"C)* Accuracy 'The temperature rating of the GPSMAP 6WCSx nxav exceed the wattle ranee GPS: <10 meters(33 feet)95%typical* UI Wille battens.Sane batten(can rupture at high temperatures. 'Subject to accuracy degradation to tONnl 2DRMS under the U.S,Dot) imposed Selectrte As ailability ISA 1 Progcan ii.lien activated. Performance DGPS: 3-5 meters(10.16 feet)95"b typical* Receiver: WAAS/CGNOS enabled .WARS accuncl in North America Acquisition Times*: Approx. 1 second(warm start) Velocity: 0.05 meter/sec steady state Approx.38 seconds(cold stars) Interfaces: NMEA 0183 version 2.3.and RS-232 and USB Approx.45 seconds(factory reset) for PC interface .110.n crr_r lora.,awrn:us rc o:rict unh am open sky,.,'. Data Storage Life: Indefinite:no memory battery required Update Rate: I/second.continuous Map Storage: Dependant on the capacity of the Antenna: Built-in quad helix.remote antenna capability. micr'SD card.* Compass Artttr c : /-5 degees',resolution:I degree .'-t,molt p ort=l of the Card rams d,has been a tt In Ioaruuine the ort for ase GPSMAP 60CSx Owner's Manual a. a E C v acror- .<"r` GARMIN. : •--::—..^-74::--::----"----------�... .� t. t. GPSMAP' 60CSx _ . -•- • w Will _ GARMIN r inn CO-)rq Trip & Waypoant Man •• r ill% 4. -..„. _ _ —. _.--........_. . .... _. . • . , iii ..:. �b�, ...... ,,,,,,T _., ,.„ __;_____„_ :______ _ , , . _ _ . _ . . ,,.. -- i . \ , I c>renwr .... r.c 1 . . ., ._,.,..i r .�- m-R 121[28201a '1©:g2 0ji or. z rO 32 Section Line Offsets: 0 TG-2 2334 ft FEL 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 ASPC NAD1927 zone 8 protracted section 32 � 4 Township 69 South Range112 West `O Seward Meridian 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 Date: 4/14/2014 3380 C Street, Suite 205 �� 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' protracted section 7 f Township 70 South Range112 West • Seward Meridian Section Line Offsets: 1831 ft FEL 106 ft FNL >r-----------2 1.--X-0 TG-4 -L-60.m 120,m 7 (-8 ,...„7"--- D (-s cr Akutan Geothermal Project South Elbow Well #4 Wellsite Location N 500 250 0 500 1,000 API 50-295-20004-00 _ Feet 1111111 Applicant: 1:6,000 City of Akutan 3380 C Street, Suite 205 Date: 4/14/2014 Anchoraae. AK 99503-3952 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@geothermalresourcegrouD.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(arma-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 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. HS-2/TG-2 1/1 Northing/Y: 6000884 NorthinglY: 56217.982 Easting/X: 444 078 EastinglX: 53122 7.841 Convergence: -0 41 38.77243 Convergence: 0 07 05.16175 Scale Factor: 0.999638372 Scale Factor: 0.999901111 Grid Shift(U.S.ft.): X/Easting=-925718.1,Y/Northing=-19631682.3 Datum Shift(m.): Delta Lat.=96.598,Delta Lon=-129.040 Remark: Corpscon v6.0.1,U.S.Army Corps of Engineers J Z7-- \\ i // / / 7,-1 / �/ / / i ..Y- 2 / / 32 33 7 /r 173---/ / r / / j /� Section Line Offsets: TG-2 2334 ft FEL (f 259 ft FSL 5 TG-2 location: / / 444,078m E 6,000,884m N WGS84 zone 3N i 5 167 833ft E ~- --/ J c,, 2_1 -7- `l 6 2-� ri-\-k- S.P / j 1,304,633ft N 5 3 1 ,D -1.-. `f f N k Zt- B / �/ / 38ft evation / i r / / PC NAD1927 zone 10 7�' / ;/ protracted section 32 5 0 / ' 4/ Township 69 South Range112 West `� i- Seward Meridian _Ji- / / / ( / / / / r s„ / /, / 7---- si/ f�/ J , (' _/..- ,,,, ,,, Akutan Geothermal Project ! Hot Springs Well #2 Wellsite Location N 500 250 0 500 1,000 API 50-295-20002-00-00 Feet Applicant: APR 0 9 2014 1:6,000 City of Akutan 3380 C Street, Suite 205 AOGCC Date: 4/8/2014 A,.....1.,,,,,,,...-, AL/ 00g11Z 'Mg') NI / / e' f 7 32 33 Section Line Offsets: TG-2 2334 ft FEL 259 ft FSL TG-2 location: 444,078m E 6,000,884m N WGS84 zone 3N 5,167,833ft E 1,304,633ft N 38ft Elevation ASPC NAD1927 zone 10 protracted section 32 � 4 Township 69 South Range112 West Seward Meridian (, Akutan Geothermal Project Hot Springs Well #2 Wellsite Location N 500 250 0 500 1,000 API 50-295-20002-00-00 RECEIVEI — — — Feet Applicant: APR 0 9 2014 1:6,000 City of Akutan 11S:111 fl r c+roof 9nI A i1 r%nr+ Date: 4/8/2014 Directional Survey Report Geothermal Resource Group G Well ID: AGP TG-2 Well Name: Hot Springs Well-Akutan Field: Hot Springs Bay V& Sect: 32 Town: 095 Rng: 112W County:Aleutians East State: AK 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 100.0 0.00 0 100.0 0.0 0.0 0.0 0.0 0.000 TOTCC 157.0 0.75 TOTCC 241.0 2.25 TOTCC 370.0 1.75 TOTCC 469.0 2.25 TOTCC 553.0 3.75 TOTCC 710.0 0.75 TOTCC 803.0 1.25 Calculations using Minimum Curvature Method Printed 14:18 26-Mar-14 RiMBase 7 0.2.114 Page: 1 of 1 AGP TG2 8/6 2 AM Survey Time of Hours Since Depth Reading Last Circ Temperature Pressure 50 2:04 12:34 155 23 100 2:09 12:39 213 46 120 2:15 12:45 223 55 140 2:20 12:50 231 65 160 2:25 12:55 237 74 180 2:30 13:00 239 83 200 2:35 13:05 243 92 220 2:40 13:10 246 101 240 2:45 13:15 249 111 260 2:51 13:21 253 120 280 2:56 13:26 260 129 300 3:01 13:31 266 138 320 3:06 13:36 267 147 340 3:11 13:41 274 156 360 3:16 13:46 277 165 380 3:21 13:51 279 174 400 3:27 13:57 282 184 420 3:32 14:02 283 192 440 3:37 14:07 285 201 460 3:42 14:12 287 210 480 3:47 14:17 289 219 500 3:52 14:22 293 229 520 3:57 14:27 298 237 540 4:02 14:32 299 246 560 4:08 14:38 301 255 580 4:13 14:43 298 264 600 4:19 14:49 290 273 620 4:24 14:54 304 282 640 4:29 14:59 304 291 660 4:34 15:04 301 300 680 4:40 15:10 305 309 700 4:45 15:15 309 318 720 4:51 15:21 310 326 740 4:56 15:26 311 335 760 5:01 15:31 311.7 344 780 5:06 15:36 313.7 353 786 5:11 15:41 313.9 353 786 5:16 15:46 314.2 350 786 5:21 15:51 314.3 347 786 5:27 15:57 316.2 353 786 5:29 15:59 315.9 353 786 6:00 16:30 314.9 353 786 7:00 17:30 315 353 786 7:29 17:59 315.2 353 786 7:30 Started pumping cold 9.6#CaCI to kill well NOTE:Well started flowing with decreased pressure on tool shortly after on bottom.Shut in well 5:28-5:29 thus pressure rose. Max Temp=316.24 F @ 5:27 AM. AGP TG2 8/6/10 7:45 PM Survey Time of Hours Since Depth Reading Last Circ Temperature Pressure 50 19:49 12:04 160 14 100 19:55 12:10 228 38 120 20:00 12:15 238 47 140 20:05 12:20 245 57 160 20:10 12:25 249 67 180 20:15 12:30 252 76 200 20:21 12:36 256 86 220 20:26 12:41 259 95 240 20:31 12:46 262 105 260 20:37 12:52 267 115 280 20:42 12:57 274 125 300 20:47 13:02 281 133 320 20:52 13:07 282 143 340 20:57 13:12 289 153 360 21:02 13:17 291 161 380 21:08 13:23 294 171 400 21:13 13:28 296 181 420 21:18 13:33 297 189 440 21:23 13:38 299 199 460 21:28 13:43 301 209 480 21:33 13:48 303 218 500 21:38 13:53 308 227 520 21:43 13:58 312 237 540 21:49 14:04 313 247 560 21:54 14:09 315 255 580 21:59 14:14 303 265 600 22:04 14:19 309 274 620 22:10 14:25 319 283 640 22:15 14:30 320 292 660 22:20 14:35 317 302 680 22:25 14:40 318 311 700 22:31 14:46 322 321 720 22:36 14:51 322 330 740 22:41 14:56 322.3 339 760 22:46 15:01 321.9 349 780 22:51 15:06 322.9 358 800 22:57 15:12 326.15 366 802 23:03 15:18 326.22 367 Slack in line AGP TG2 Run 1 8/7/10 7:45 AM Survey Time of Hours Since Depth Reading Last Circ Temperature Pressure 50 7:55 24:10:00 180 15 100 8:00 24:15:00 238 38 120 8:05 24:20:00 246 48 140 8:11 24:26:00 253 57 160 8:16 24:31:00 257 66 180 8:21 24:36:00 260 76 200 8:26 24:41:00 263 86 220 8:31 24:46:00 267 95 240 8:37 24:52:00 269 105 260 8:41 24:56:00 274 115 280 8:47 25:02:00 281 125 300 8:52 25:07:00 289 133 320 8:57 25:12:00 290 143 340 9:03 25:18:00 297 153 360 9:09 25:24:00 300 161 380 9:16 25:31:00 301 171 400 9:21 25:36:00 303 181 420 9:27 25:42:00 305 189 440 9:32 25:47:00 306 199 460 9:37 25:52:00 308 209 480 9:42 25:57:00 309 218 500 9:47 26:02:00 315 227 520 9:52 26:07:00 318 237 540 9:57 26:12:00 320 247 560 10:02 26:17:00 321 255 580 10:07 26:22:00 311 265 600 10:12 26:27:00 315 274 620 10:17 26:32:00 325 283 640 10:22 26:37:00 326 292 660 10:27 26:42:00 323.7 302 680 10:32 26:47:00 325.2 311 700 10:37 26:52:00 326.7 321 720 10:42 26:57:00 326.5 330 740 10:47 27:02:00 326.3 339 760 10:52 27:07:00 325.6 349 780 10:57 27:12:00 325.9 358 800 11:03 27:18:00 328.2 366 802 11:08 27:23:00 328.2 366 Slack in line Max Temp recorded=328.25 F AGP TG2 RUN 2 8/7/10 7:45 PM Survey Time of Hours Since Depth Reading Last Circ Temperature Pressure 50 19:54 36:09:00 188 15 100 19:59 36:14:00 243 38 120 20:04 36:19:00 251 48 140 20:09 36:24:00 258 57 160 20:14 36:29:00 262 66 180 20:19 36:34:00 265 76 200 20:24 36:39:00 268 86 220 20:30 36:45:00 273 98 240 20:35 36:50:00 273 107 260 20:40 36:55:00 279 116 280 20:45 37:00:00 287 125 300 20:50 37:05:00 296 137 320 20:56 37:11:00 299 146 340 21:01 37:16:00 303 155 360 21:06 37:21:00 305 165 380 21:12 37:27:00 307 174 400 21:17 37:32:00 309 183 420 21:23 37:38:00 310 193 440 21:28 37:43:00 311 202 460 21:33 37:48:00 313 211 480 21:38 37:53:00 314 221 500 21:43 37:58:00 321 230 520 21:48 38:03:00 323 239 540 21:53 38:08:00 325 248 560 21:59 38:14:00 325 257 580 22:04 38:19:00 304 268 600 22:09 38:24:00 323 277 620 22:14 38:29:00 329.7 285 640 22:19 38:34:00 328.3 295 660 22:25 38:40:00 327.5 303 680 22:31 38:46:00 329.1 313 700 22:36 38:51:00 329.6 322 720 22:42 38:57:00 329 332 740 22:47 39:02:00 328.5 341 760 22:52 39:07:00 327.6 350 780 20:57 37:12:00 328.3 360 800 23:01 39:16:00 329.4 366 Slack in line Max Temp recorded=330.2 F @ 620' Guhl, Meredith D (DOA) From: Mary Ohren [maryohren@geothermalresourcegroup.com] Sent: Tuesday, March 11, 2014 2:50 PM To: Guhl, Meredith D (DOA); Schwartz, Guy L(DOA) Cc: 'Joe Bereskin'; 'Mary Tesche'; kmmann@rma-cg.com; Hermann Scanlan; 'R Mann'; Bill Rickard Subject: RE: Reporting Compliance Hot Springs Well 2 Attachments: Hot Springs Bay#2 Continuous Output.pdf; DirectionalSurveyRpt_AGP-TG-2.xls Meredith, I am with Geothermal Resource Group,geothermal and drilling consultant to the city of Akutan, assisting with the project. Formally your office was in contact with Alan Bailey of this office, but I will now be the point of contact for the Akutan geothermal drilling. The two wells were drilled as temperature gradient wells, never intended to flow or be productive.TG-2 was flowed naturally during drilling, it was allowed to flow in order to get water samples that would aid in resource evaluation. There was no flow test equipment in place and all of the data that was collected during that test qualitative and quantitative was passed along to you in the most recent delivery from the City of Akutan. If something was overlooked in this delivery in regards to the pressure data I will send it along. I am sending the additional requested documents that I have on-hand right now attached to this email.These are the pdf of the mudlog and the inclination report. The well location is 2325'E, 500'S,S32,T69S, R112W SM as referenced to section lines and 531250 E,56490 N Zone 8 based in State Base Plane Coordinates NAD 27. I will send the remaining items as they become available. My contact information is below. 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. From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: Monday, March 10, 2014 10:11 AM To: akutanadmin@gci.net Cc: Davies, Stephen F (DOA); Schwartz, Guy L(DOA) Subject: Reporting Compliance Hot Springs Well 2 Dear Mr.Scanlan: 1 I am completing the final compliance check for Hot Springs Well 2, PTD 210-071,API 50-295-20002-00-00, abandoned 9/14/2013. 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 Hot Springs Well 2. 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 Hot Springs Well 2. 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 June 23, 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 Hot Springs Well 2. 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.Buhl@alaska.gov Direct: (907)793-1235 2 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 Hot Springs Well 2 Dear Mr. Scanlan: I am completing the final compliance check for Hot Springs Well 2, PTD 210-071,API 50-295-20002-00-00,abandoned 9/14/2013. 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 Hot Springs Well 2. 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 Hot Springs Well 2. 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 June 23, 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 Hot Springs Well 2. 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 -2:59-2.21 41-2 3",21 FEB 19 2014 2_10 - b7 3 DATA LOGGED z39 O AKUTAN AoGoc M K BENDER UNIMAK ISLAND AKUTAN y. ' 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, /414 1 Mary Tesche Assistant City Administrator City of Akutan 907.777.1643 RECEIVED FEB 192014 AOGCC Supplementary Materials for Akutan Hot Springs Well 2 and South Elbow Well 4 Contents Tab File Name File type 1 DrillingPaper_GRCVo135 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 11 +II Pi wail.MI6_ 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. -,— ,.,; ie -c.____4( lorpow-_:A......Rip _ • " 4L - - 1,..k P."*0-; -'7'-''',..,,, Vm-- , - '7', ii '''il Ild ii.N....s. Ai, ic -4.•00'' 11P, ,, ' c33TiT, . , J V '�.`� ,HSS i ' �� t r/ i.,'��'7 �� J/�//ter►..1..�t7-1���'---- .71,,,'„1l r ..�i 6 t' t'470.0 :M `r<JC'`s_ r--=�\Jffi4 _ - 54 "0 J//L _ ""Al..._ Jl[�t :k -----41n, . --- (.;, .. ..-.8" , ri .' '1/4._Z iWair I Q, - " lr ; ,,--A lib L -.‘...,....,%leki / 2 xii�!� 4,is. , Nisio<cpq:S,...„,,mw-,„... ....*!_>..;(/"...1, .14.4; (.04,1 IN, 7%1, : PlIA ‘.1,VA"k,....,;::;.0.116 #' ,P •‘..4 -•\4 . „ , , , .„ ,.....„.. .... 4 Ak. ..: , 1 ....41Q1 i ' r. �� y Miles ';_.,, Fumaroles ` • 0.25 0.5 1 1.5 2 ' - Well Location i' , Meter ', 1� 250 500 1,000 1,500 2,000 ' r.___ ,,r+ • Hot spring . <, (y✓ ••-Transmission Lines lapprox • ✓//J��_^ N, Akutan project 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 ■ 141 5-',6"Oversize PQ Core to 150' 4-W"HWT 11.2#/ft 4130 Butt Casing to 150' 3.78"HQ Core to 600' HQ 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' PQ hole; PQ hole; HW casing HW casing (4.5"0.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 • storage ABO' ►7/6"valve ONNII MC! —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. k't IA 1 i/ • ato 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 7, 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 Atimen 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. C - ! r WuunC L.ewI e Mils FILL bill al S711 It- 53 t- 53 - .u410 100 - 150 - 4 soave.FU-1 w1 at 15701 at 20- _,JL10 200 - 253 - 300 - 353 - 400 - 450 - 03 - F53 - 603 - 360C*,*h 0.1 >.d d df u•;3 Ja410 653 - 703 — 753 - ec F3 - t e iins Hhfs CM tel se diet tr - h`,I ut�sq-1C Tote DWptt.ea9t Cyan rf uU Osman 5 c Yt t•a 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:Aleutans East State:AK C • Actual 100 -0—Planned d • JJ 203 I - 300 II :2THEP 400 -- 900 I +1,- I eonBOPOPS - 4\4- 70,2_c CEMENT ihmilTO'c a KCN 900 EVALUATE '.7C 1000 1100 MOB 79.00 1203 PROBLrt4 _ 12e.SC. 1300 A 1400 lDRI__ - 143 50 1503 • r 1 1 I 1 C c 10 •5 23 25 33 3 50 103 •5C 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 7/8" bit to 38', and 33' of conductor was set from 5' to 38' (conductor has inner diameter of 6 5/8"). 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 7). 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 - 0 -_ to 510', when the crew had to pull out for a Ground Level 6.6251nsFUL-eel at361on 12- new bit, and then had a stuck core barrel @ Aug-10 527'. At 596', the second string of casing 00 was installed (HQ with an inner diameter of ■ 450oInsFUL_set at16ot'on 15- 200 - Aug-10 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 (600'). 500 - From 600' to 1500', drilling proceeded very 600 - S3oinsFUL_se at555ro- •5- rapidly with little to no communication Aug-10 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. 10 500 - shows graphical representations of drilling progress while on location for TG-4. 900 - 1000 - 1100 - Figure 8. Schematic of the final wellbore configuration 1200 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". - 1 1400 - I� fit 1500 - Toch C•e_:-i 1 ICC". €W 3 n211-5 9 Akutan Geothermal Project Summary of Findings from the 2010 Exploratory Drilling Program 100 - 1 Actual l� Planned PROBLM • • 200 - k OTHER 300 - 400 : I _ ` EVALUATE 500 - 600 - • • CASING II 0 02 • 700 •. • TRIP 14.75 a 800 - a) 0 900 - BOPOPS 15.00 1000 - 1100 - MOB 30 50 1200 - • CEMENT 48.50 1300 - • 1400 - DRILL 147.75 1500 - • - . ■ • 1 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. AGPTG28.6.10Run I TempSune� P assure Temperature Temperature Exl 500 '. ._ 300 450 400 250 35C 300 2000 m .5250 rt 200 I 15C 150 loo _._ __ _._ 10C 50 5C 0 e.41 6 F rr Aug 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 s'"200 p$7 200 O 150 150 100 100 50 0 8PM 9PM 10PM 11PM 6 Fn 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 350 300 300 250 250 200 01. 200 a / _ 150 T 150 100 100 50 0 50 8PM 9PM 10PM 11PM 30 Mon Aug 2010 Time Figure 12. Third of three end-of-well PIT 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 TC4 8/22/IO Run 1 • Pressure Temperature --- Temperature Ext i ri t IV t}� lilt'b 40 ��t� it 650 600 _ G�^1! 300 � 550 w� y 0 N� 5 Pb9t+O.�e PN. 250 .� \ `Pv°ve ���� ,1./ 1 (W 1\ N 3 NO- 4, �o f 200m' L.:: , tr ,600 .. • : iv , „Is) 8 250-: ¶50 200 150 ,00 100 - 50-- - ye 50 0-" 6AM 9AM 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•927.52 Pressure Temperature Temperature Ext 650 600 300 550 500 250 fid ` 1350 200.. og 900-_ d5 250 .. .. 150 200 150 100 100 50 6PM 9PM 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 1 Final Sun e) MAXIMUM TEMPERATURE-377.81 1 Pressure Temperature Temperature Ext 650 600 300 550 500 250 450 —400 0 200 d 350 z a eL 300 250 150 200 150 100 100 50 6AM 9AM 23 Mon Aug 2010 Time Figure 16. Third of three end-of-well P/T 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 'ret-st Iid0Prepared by Prospet Geote +1- 165 PSI 100 Ili/ 130-PSI-Stable _ 35 PSI p 'Current(PSI) (.0 N O N In N O N U N O r� rn N O N LO N O t. Ln N O N m Cr Cr Lr1 O .--t .7 7 F.1 O .--t .--t N m Irl O 01 Q1 C C FT 0 0 0 0 0 N O O O O O •-+ `""1 .--I .--I '-+ .-i .--I .--1 .--I .-i .--1 .--1 .--I .-i c-I .--1 .--t .--1 .-1000000000000000000 00000 .-1 c-I .--I .--I .--I .--I ci ci c-1 c-1 .--1 .-1 .--1 .--1 ♦-i .--I .--I .--I 00000000 0000000000 N N N N N V V V V V V V V V V V 7 7 .7 7 \ \ \ \ \ N N N N N N N N N N N N N N N N N N CO 00 00 CO 00 \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ 00 00 00 00 00 00 00 CO 00 00 CO CO 00 00 00 00 00 00 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 Horner 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 1f5.0 ------------------... 557.0 1 USD ♦See. 1M.0 1113.0 16.2.0 5.000000011 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 — 0 -200 -400 .1".1 H W -600 ca -800 ai -1000 ----,_ TG2 -TG4 -1200 _— -Boiling Curve 0.1%NCG -1400 —Flowing MRT TG2 -1600 Figure 19. Estimated equilibrated Temp v. depth plot for Akutan TG wells, based on Homer 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 miti, of. s , t rA A r1 Vi - 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 _ Q 400 a, ai 500 ns ' 600 _1 700 12h 08-2010 24h 08-2010 800 - 36h 08-2010 May-11 900 1 Nil1 , T 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) 0 200 400 600 ......... .... J Q 800 cu Gl 1000 . 0 1 w> 1200 W 1400 — 12h 08-2010 Q 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 1 —_ w 800 C 0 1000 – ca ru 1200 - _ - TG2-05-2011 1400 TG4-05-2011 * —Boiling 0.1%NCG 1600 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. W N__s_ -„,.r,o--1,6 _ `121.S. - —`L -- - .-- k / 3 . i — T $” _ _ f418 9 . V — 10 a h .... "Ohlit i 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. I. A I W ✓ wyY a` 114:- 4;411.,. ".7 . ▪. t A r 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. 3- g.S 52� ._.: .; .< -... .. ., ... _. .. `'.,..qac.—.wa5�a�neaer�v I ill ' '1 .-y *{ W 4N' ~ .may t ilk I 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 1,. 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 FeO 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 «i.- - ii,)♦�: . s -MP = -- - . ^LI. ,_fir-44....+14 4. <' F 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. • 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. 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 H25 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 CI 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 -#- 'i , 7; to 178 m. The second well (TG-4)was drilled at the margins • , ,,,,� � . ) r o", i ?, of the modeled outflow in order to conceptualize the size of �.•"'t • x ' :: tib, ; ,., , the outflow resource. That well had very low permeability but ",` <, p, •-N ; . ''�'�� 11r, t*. displayed a high temperature gradient, with an extrapolated ` �a "' . t.r �,` .� ./ • t' - temperature of 164 deg C at 457 m.Some evidence that a deeper, 1 tri ( ,,� ` :'}t ,,- c hotter resource exists at or near the TG-4 site was found using ?'• . �_ j-� d w�1 —,h mineralogical data. Preliminary analysis of data suggests that 't) v ham" 4--- a a pumped production well at the TG-2 site would be capable of — 1 �-- ..,..,;,; ,P•'-'-\t`�, - 1 \ w • � i a maximum production of 2.3 MW. Geochemical sampling of • "`� ys' ��" `" . the fumarole gasses was carried out on the flank of the Akutan `b. y Volcano concurrent with the drilling. The data obtained from ': k, x7+�''� , J `•' 1 ";i S. drilling will be combined with core and geochemical analysis - J, ,�` �'r �' ;_i ;a, to order to form a resource model of the field preliminary to , ` —�.••• production drilling. M»� f � s"� ,o• ,' —,,,,�' 1509'2-4"7---.7r,. {a, J� . `,- --- Introduction — — f! `' ' �!1 '- ,�� .._ 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. used 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- r tion was stopped or slowed,the well flowed.The well showed a particular propensity to flow hen led 13.c7 HWT O 11 1 ize2# . Core i 45 in fromthe well due to changes Vin the the pressure diffe ent al —t a a3 cm 11.2M'&4130 Bu"Casing lo- 45.7m and the fact that it is not possible to run inside blowout protection when wireline coring. 9 6 cm HO Co-e to 182 9m Throughout the drilling,downhole temperatures were recorded --.89 cm HO 7.67 kit 413C Bun Casng to- 182 9m at 30'intervals with a maximum registering thermometer(MRT). These temperatures are not accurate records of the true geothermal -x.22 cm Tubing hunp 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 -----757«t,NO Com to-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 DrillingOperations amount of cement was squeezed around the shoe and into the P 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-offtests)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 rii 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 m circulation,and regular f 1 j 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. so p -- PT Data ___ _ _._ _ _ —..-- A memory-type Pressure/Temperature(PT)tool was used for -leo - - the end-of-well PT surveys. Three runs were recorded at 12,24 _IseI - and 36 hours after circulation ended. For every run, stops were r made at 6.1m stations. Because these surveys were taken so a-200 - soon after the well was drilled,the temperature readings are still ° -zso ' - influenced by the cooling effects of fluid circulation. Therefore Wk�_ the data represent unequilibrated downhole temperatures. 300 -`—TG2 In order to predict the equilibrated downhole temperature, - ---TG` - -- -____ ---Bailinycww a1':NCG we used the Horner method to extrapolate ultimate values for the Wo —_Sloane MU reservoir temperature based on curves generated from the three 11 1 I I I I I I survey points from each depth. An example of an extrapolation -450 is shown in Figure 4. - The final depth vs.temperature plot generated from extrapo- Figure 5.Plot of Homer-extrapolated TG data from Akutan Geothermal 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 178.31 m. Closest fit zea.ametersr._�______-_______�___.._._ .Wa Geology ,,,G -400 Cr — Complete mud logs were recorded for both TG wells.In gen- eral, the formations encountered were generally homogeneous Iwo 11(---\,...„, — volcanic flows of andesite, basaltic andesite, and basalt. While heavy oxidation(Fe oxides)was observed between flow layers, i"" ._,F, hydrothermal mineralization was confined to small <30cm) as _ �� fractures within the flows.Figure 6 gives an example of a typical �� core box for well TG2. It]. In the basalt and andesite flows,fractures were oriented in 2 distinct directions: 1)generally subhorizontal(25 degrees off ver- 161. ..... tical)and 2)subvertical.The subhorizontal fractures were larger _____ _._ 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). .. _- 425 5 u.38 I i l I i ! 1 Although the downhole surveys show a drop in temperature • • .. - i I 1 I-1 I 1 i i -III t between 179.83m and 188.98m, we know that the downhole 1 1 1 1 ,t 1. 1 temperature was actually 181.67 °C between 178.31-178.92m � Ii f i I I from the MRT reading. The apparent cooling is likely the result i -I I i ' r t , I I of cement injected across that entire area for the leak off test. The plot of the extrapolated temperature vs depth for Well TG4 shows a relatively rapidly increasing temperature gradient IIIIIII"°, r . _. . 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 'OW1 from small fracture sets.The facts that there was no temperature reversal and that the gradient continues to increase suggest there • i 1 i i i i1 f i r f-•i i..i. -1 I l i -14- could be a deeper, hotter aquifer below 457.2m that was not penetrated by drilling. L illr An injection test was performed on well TG4 to determine its -,_._r.... 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#1-1 1 in photo)and andesitic tuff(sections#11-15 in below 457.2m if a deeper,hotter aquifer exists. photo). 849 Kolker,et al. d5$L ?9 r I I. `. tt '1 wx r '. y, ti immopy* . 1 • * IS, .:11'.:' 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 ' ,:,. •, hyo *a' 1 filled with laumontite or calcite. Above —177.lm, the vugs in '' r . #" :.,. vesicular portions of the flows were filled with a combination of ► ' t s3. " calcite and chlorite. Between --177.1m and —216.4m, the vugs p • 4,,, u` ?` ,' , ' { '! "4 in vesicular portions of the flows were filled with a combination �' ►: I ''" ' of calcite,chlorite,epidote,and rare laumontite.The productive ` ,-,, ': l , fracture at 178.31-178.92m had calcite,laumontite,chlorite,epi- tm dote, arsenopyrite, and cinnabar. Within the productive fracture I " r i I 1 I and some vesicles below 177.1m,epidote displayed an interest- I ing morphology, with radiating euhedral crystals nucleating on 1 i i I i i top of chlorite vein fill.Additional mineralized zones occurred at 1 210.3m and 214.9m,though the fractures in these zones did not _T 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 A 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 tern- 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 6.1m 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-178.92m. larger-diameter wells. 851 a) L C N L f0 LL 1 91:£1OZ-80-80 !I ..................,..........................." LS:Z1 01-80-80 6£:Z1 01-80-80 OZ:ZI 01-80-80 ZO:Zi 01-80-80 £b:11 01-80-80 SZ:1101-80-80 r- --' 90:ii 01-80-80 817:01 01-80-80 �� £ 6Z 01 01-80-80 ' baCfl. 11:01 01-80-80 O L_ '3 oA ZS:60 01-80-80 '1 Oul 00 3 . uo b£ 60 01-80-80 S1:60 01-80-80 00 LS:80 01-80-80 4-+ H 8E:80 01-80-80 Au OZ:80 01-80-80 10:80 01-80-80 £b:Lo 01-80-80 0 bZ:LO 01-80-80 LL 90:L0 01-80-80 N L17:90 01-80-80 6Z:90 01-80-80 CL 01:90 01-80-80 0 ZS:SO 01-80-80 Q EE:SO 01-80-80 Si:SO 01-80-80 0 LLE 95:170 01-80-80 Ci a- ILO 8£:b0 01-80-80 61:170 01-80-80 QC IN 'ti. II TO:170 01-80-80 2 -p Zb:£0 01-80-80 1Z:£0 01-80-80 S0:£0 01-80-80 Lb:ZO 01-80-80 8Z-Z0 01-80-80 Oi-ZO 01-80-80 i5:10 01-80-80 ££:10 01-80-80 171.10 01-80-80 95:00 01-80-80 4__ LE:00 01-80-80 0 0 0 0 0 0 N 0 N u'1 (j)ainleaadwal O 0 Cr 0 I!- - M O r�r/C O . ' . M p / 4-...• ao ' r r / / ' O 4. j N _ y H d rr I 7 1- 3O as O • — i N Q N , I H H • I O In - r-i o •-i ,-I - 1-1 1-1 O O O N N N O O O O `� 1 1 O t t L �O 1-i N M • I I II":I O r In O , 0 0 0 0 0 0 0 0 0 0 el N M to l0 N 00 Cl (4) 4;daa AGP TG2 AGP TG2 AGP TG2 AGP TG2 8/7/2010 12h 8/8/2010 24h 8/8/2010 36h 5/22/2011 Survey Run #1 Run #2 Run #3 One run Depth (ft) Temp (°F) Depth (ft) Temp (°F) Depth (ft) Temp CO Depth (ft) Temp (°F) 46 160 46 180 46 188 16 217.3 96 228 96 238 96 243 36 218.3 116 238 116 246 116 251 56 220.5 136 245 136 253 136 258 76 224.5 156 249 156 257 156 262 96 234.3 176 252 176 260 176 265 116 240.4 196 256 196 263 196 268 136 245.3 216 259 216 267 216 273 156 249.7 236 262 236 269 236 273 176 254.3 256 267 256 274 256 279 196 249.7 276 274 276 281 276 287 216 254.3 296 281 296 289 296 296 236 260.1 316 282 316 290 316 299 256 267.3 336 289 336 297 336 303 276 273.2 356 291 356 300 356 305 296 278.7 376 294 376 301 376 307 316 283.5 396 296 396 303 396 309 336 290.7 416 297 416 305 416 310 356 295.3 436 299 436 306 436 311 376 300.9 456 301 456 308 456 313 396 306.2 476 303 476 309 476 314 416 310.2 496 308 496 315 496 321 436 325.6 516 312 516 318 516 323 456 328.2 536 313 536 320 536 325 476 330.8 556 315 556 321 556 325 496 332.4 576 303 576 311 576 304 516 333.5 596 309 596 315 596 323 536 334.8 616 319 616 325 616 329.7 556 336.8 636 320 636 326 636 328.3 576 337.3 656 317 656 323.7 656 327.5 596 337.5 676 318 676 325.2 676 329.1 616 337.2 696 322 696 326.7 696 329.6 636 336.5 716 322 716 326.5 716 329 656 336 736 322.3 736 326.3 736 328.5 676 335.7 756 321.9 756 325.6 756 327.6 696 334.9 776 322.9 776 325.9 776 328.3 716 333.9 796 326.15 796 328.2 796 329.4 736 333.2 798 326.22 798 328.2 798 756 332.3 796 326.15 796 328.2 796 329.4 776 330.2 798 326.22 798 328.2 798 796 330.2 796 330.2 Daily Drilling Report Geothermal Resource Group 11$ Well ID: AGP TG-2 Well Name: Hot Springs Well -Akutan Field: Hot Springs Bay Va Sect: 32 Town:095 Rng: 112W County:Aleutians East State:AK Report No: 1 Report For 10-Jul-10 Operator: City of Akutan Rig: Major LF90 Spud Date: 16-Jul-10 Daily Cost/Mud($): Measured Depth(ft): 0 Drilling Days(act.): 1 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 0 Drilling Days(plan): 22 RKB Elevation(ft): 4.00 --- Proposed TD(ft): 1500 Days On Location: 1 Last BOP Test: Hole Made(ft)/Hrs: 0/0.0 Last Casing: Totals Average ROP(ft/hr): Next Casing: 6.625 at 30 Working Interest: Well Cost($): Personnel: Operator: 3 Contractor: 3 Service: 6 Other: 2 Total: 14 Current Operations: Operations idle for night. Planned Operations: Continue to mobilize rig and equipment. Toolpusher: David Griggs. Wellsite Supervisors: Alan Bailey,Randy Baldwin Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 7:30 17:30 10.00 0 MOB Sling loads to drill site. Dug cellar and began constructing sump. Comments Well site under construction. Began moving equipment to well site. Rig Information Equipment Problems: Location Condition: Transport: Safety Information Meetings/Drills Time Description Safety 15 Pre-job safety meeting with all personnel, First Aid: Medical: Lost Time Accidents: Days Since LTA: 0 ❑ BOP Test Crownamatic Check Printed: 09:14 14-Feb-14 RIMBase 7.0.2.114 Page: 1 of 1 Daily Drilling Report Geothermal Resource Group Well ID:AGP TG-2 Well Name: Hot Springs Well-Akutan Field: Hot Springs Bay W Sect:32 Town:095 Rng: 112W County:Aleutians East State:AK Report No: 2 Report For 11-Jul-10 Operator: City of Akutan Rig: Major LF90 Spud Date: 16-Jul-10 Daily Cost/Mud($): Measured Depth(ft): 0 Drilling Days(act.): 2 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 0 Drilling Days(plan): 22 RKB Elevation(ft): 4.00 --- Proposed TD(ft): 1500 Days On Location: 2 Last BOP Test: Hole Made(ft)/Hrs: 0/0.0 Last Casing: Totals Average ROP(ft/hr): Next Casing: 6.625 at 30 Working Interest: Well Cost($): Personnel: Operator: 3 Contractor: 3 Service: 6 Other: 3 Total: 15 Current Operations: Rig idle for night. Planned Operations: Continue to mobilize rig and equipment. Toolpusher: David Griggs. Wellsite Supervisors: Alan Bailey, Randy Baldwin Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 7:30 20:00 12.50 0 MOB Sling loads to camp and well site.Constructed sump at rig site.Set and leveled rig base. Comments Unloaded containers,continued to move loads to drill site and camp.Continued well site construction.Set-in and leveled rig base. Rig Information Equipment Problems: Location Condition: Transport: Safety Information Meetings/Drills Time Description Safety 15 Pre-job safety meeting with all personnel, First Aid: Medical: Lost Time Accidents: Days Since LTA: 1 ❑ BOP Test ❑ Crownamatic Check Printed: 09:14 14-Feb-14 RIMBase 7.0.2.114 Page: 1 of 1 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well-Akutan Field: Hot Springs Bay Ve Sect:32 Town: 095 Rng: 112W County:Aleutians East State:AK Report No: 3 Report For 12-Jul-10 Operator: City of Akutan Rig: Major LF90 Spud Date: 16-Jul-10 Daily Cost/Mud($): --- Measured Depth(ft): 0 Drilling Days(act): 3 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 0 Drilling Days(plan): 22 RKB Elevation(ft): 4.00 --- --- --- Proposed TD(ft): 1500 Days On Location: 3 Last BOP Test: --- --- --- Hole Made(ft)/Hrs: 0/0.0 Last Casing: Totals --- --- Average ROP(ft/hr): Next Casing: 6.625 at 30 Working Interest: Well Cost($): --- Personnel: Operator: 3 Contractor: 3 Service: 6 Other: 4 Total: 16 Current Operations: Rig idle for night. Planned Operations: Continue slinging loads to camp and rig site.Continue digging sump.Rig up camp. Toolpusher: David Griggs. Wellsite Supervisors: Alan Bailey, Randy Baldwin Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 7:30 19:30 12.00 0 MOB Moved loads to camp and rig site.Set up VHF repeater.Continued digging sump at rig site. Comments Moved equipment to well site and camp. Set up VHF communications. Continued sump construction. Rig Information Equipment Problems: Location Condition: Transport: Safety Information Meetings/Drills Time Description Safety 15 Pre-job safety meeting with all personnel, First Aid: Medical: Lost Time Accidents: Days Since LTA: 2 ❑ BOP Test ❑ Crownamatic Check Printed: 09:14 14-Feb-14 RIMBase 7.0.2.114 Page: 1 of 1 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well-Akutan Field: Hot Springs Bay Va Sect:32 Town:095 Rng: 112W County:Aleutians East State:AK Report No: 4 Report For 13-Jul-10 Operator: City of Akutan Rig: Major LF90 Spud Date: 16-Jul-10 Daily Cost/Mud($): Measured Depth(ft): 0 Drilling Days(act.): 4 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 0 Drilling Days(plan): 22 RKB Elevation(ft): 4.00 --- Proposed TD(ft): 1500 Days On Location: 4 Last BOP Test: Hole Made(ft)/Hrs: 0/0.0 Last Casing: Totals Average ROP(ft/hr): Next Casing: 6.625 at 30 Working Interest: Well Cost($): Personnel: Operator: 3 Contractor: 4 Service: 7 Other: 3 Total: 17 Current Operations: Rig idle for night. Planned Operations: Continue to sling loads to drill site.Finish rigging up rig and setting up camp site.Complete sump. Toolpusher: David Griggs. Wellsite Supervisors: Alan Bailey, Randy Baldwin Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 7:30 20:00 12.50 0 MOB Continued moving material to camp and to well site. Continued digging sump.Began rigging up. Comments Continued moving equipment to well site and camp and began rigging up. Rig Information Equipment Problems: Location Condition: Transport: Safety Information Meetings/Drills Time Description Safety 15 Pre-job safety meeting with all personnel, First Aid: Medical: Lost Time Accidents: Days Since LTA: 3 ❑ BOP Test ❑ Crownamatic Check Printed: 09:14 14-Feb-14 R/MBase 7.0.2.114 Page: 1 of 1 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well -Akutan Field: Hot Springs Bay Ve Sect: 32 Town:095 Rng: 112W County:Aleutians East State:AK Report No: 5 Report For 14-Jul-10 Operator: City of Akutan Rig: Major LF90 Spud Date: 16-Jul-10 Daily Cost/Mud($): --- Measured Depth(ft): 0 Drilling Days(act.): 5 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 0 Drilling Days(plan): 22 RKB Elevation(ft): 4.00 --- --- --- Proposed TD(ft): 1500 Days On Location: 5 Last BOP Test: --- --- --- Hole Made(ft)/Hrs: 0/0.0 Last Casing: Totals --- --- Average ROP(ft/hr): Next Casing: 6.625 at 30 Working Interest: Well Cost($): --- Personnel: Operator: 3 Contractor: 7 Service: 7 Other: 5 Total: 22 Current Operations: Rig idle for night. Planned Operations: Sling loads. Pre-check rig, raise derrick. Rig up pumps and mud pits. Toolpusher: David Griggs. Wellsite Supervisors: Alan Bailey, Randy Baldwin Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 7:30 19:30 12.00 0 MOB Unable to sling loads due to fog.Continue rigging up camp.Continue rigging up rig. Finish digging sump. Install sump liner. Comments Weather delay due to foggy conditions-helicopter could not sling loads.Continued to rig up and set up camp. Sump was completed and liner set. Rig Information Equipment Problems: Location Condition: Transport: Safety Information Meetings/Drills Time Description Safety 15 Pre-job safety meeting with all personnel, First Aid: Medical: Lost Time Accidents: Days Since LTA: 4 ❑ BOP Test ❑ Crownamatic Check Printed: 09:14 14-Feb-14 R/MBase 7.0.2.114 Page: 1 of 1 Daily Drilling Report Geothermal Resource Group 604tWell ID: AGP TG-2 Well Name: Hot Springs Well-Akutan Field: Hot Springs Bay Ve Sect:32 Town:095 Rng: 112W County:Aleutians East State:AK Report No: 6 Report For 15-Jul-10 Operator: City of Akutan Rig: Major LF90 Spud Date: 16-Jul-10 Daily Cost/Mud($): --- Measured Depth(ft): 0 Drilling Days(act.): 6 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 0 Drilling Days(plan): 22 RKB Elevation(ft): 4.00 --- --- --- Proposed TD(ft): 1500 Days On Location: 6 Last BOP Test: --- --- --- Hole Made(ft)/Hrs: 0/0.0 Last Casing: Totals --- --- Average ROP(ft/hr): Next Casing: 6.625 at 30 Working Interest: Well Cost($): --- Personnel: Operator: 3 Contractor: 7 Service: 7 Other: 5 Total: 22 Current Operations: Rig idle for night. Planned Operations: Finish rigging up. Hold safety meeting and drill ahead. Toolpusher: David Griggs. Wellsite Supervisors: Alan Bailey, Randy Baldwin Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 7:30 21:00 13.50 0 MOB Continued rigging up rig.Raised mast. Installed new wire line.Added mixing water to sump and pits. Began building bridges over creeks going to camp. Comments Continued rigging up. Raised the mast and installed new wire line.Added mixing water to sump and pits. Bridged creeks going to camp. Rig Information Equipment Problems: Location Condition: Transport: Safety Information Meetings/Drills Time Description Safety 15 Pre-job safety meeting with all personnel, First Aid: Medical: Lost Time Accidents: Days Since LTA: 5 ❑ BOP Test ❑ Crownamatic Check Printed: 09:14 14-Feb-14 RIMBase 7.0.2.114 Page: 1 of 1 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well-Akutan Field: Hot Springs Bay V8 Sect:32 Town:095 Rng: 112W County:Aleutians East State:AK Report No: 7 Report For 16-Jul-10 Operator: City of Akutan Rig: Major LF90 Spud Date: 16-Jul-10 Daily Cost/Mud($): --- Measured Depth(ft): 37 Drilling Days(act.): 7 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 37 Drilling Days(plan): 22 RKB Elevation(ft): 4.00 --- --- --- Proposed TD(ft): 1500 Days On Location: 7 Last BOP Test: --- --- --- Hole Made(ft)/Hrs: 37/3.5 Last Casing: Totals --- --- Average ROP(ft/hr): 10.57 Next Casing: 6.625 at 30 Working Interest: Well Cost($): --- Personnel: Operator: 3 Contractor: 7 Service: 7 Other: 4 Total: 21 Current Operations: Opened hole to 7-1/2 inches f/25't/37'with full returns. Temp out=52 degrees. Planned Operations: Open hole to 9 7/8 inch.Run and cement 6 5/8 inch conductor, Toolpusher: David Griggs. Wellsite Supervisors: Alan Bailey,Randy Baldwin Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 7:30 14:00 6.50 0 MOB Finished rigging up. 14:00 15:00 1.00 0 MIXMUD Mixed spud mud. 15:00 15:30 0.50 0 SAFE Held pre-spud safety meeting. 15:30 19:00 3.50 37 DRIL Cored 5 1/2 inch hole surface to 37'with full returns. No fill. 19:00 19:30 0.50 37 TRPO POH. Hole flowed approx 5 gals/min.of 120 degree water. 19:30 0:00 4.50 37 OPEN MU 7-1/2"milltooth bit.Opened hole surface to 25'. Management Summary 9-7/8"bit in Dutch Harbor-unable to mobilize it due to weather. Comments Rig idle for night.Finished rigging up.Held safety meeting with all crew members.Mixed spud mud.Cored 5-1/2"hole surface to 37'.Opened hole to 7-1/2"t/25'. 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-Jul-10 12:00 at Depth 0 ft Sample from Mud Pits,Type:Low Solids Non-Dispersed 8.50 45 52 52 Mud Consumables Item Description Qty. Cost Item Description Qty. Cost Gel-100#SK 42 --- Soda Ash-50#SK 3 --- 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 ADT 2A0 5.500 0 37 4 9.2 9 Jets: Out: 37 Grade: Cutter: 2/2 Dull WT/ Wear:A Brgs: Gge: 0 Pull: TD 2 1 B HUGE GT-1 7.500 0 25 4.5 5.6 80 9 200 Jets: 18 18 18 Out: 37 Grade: Cutter: 2/2 Dull WT/NO Wear:A Brgs: E Gge: 0 Pull: TD Rig Information Equipment Problems: Location Condition: Transport: Safety Information Meetings/Drills Time Description Safety 15 Pre-job with both crews. First Aid: Medical: Lost Time Accidents: Days Since LTA: 6 ❑ BOP Test ❑ Crownamatic Check Printed: 09:14 14-Feb-14 RIMBase 7.0.2.114 Page: 1 of 1 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well-Akutan Field: Hot Springs Bay Ve Sect: 32 Town:095 Rng: 112W County:Aleutians East State:AK Report No: 8 Report For 17-Jul-10 Operator: City of Akutan Rig: Major LF90 Spud Date: 16-Jul-10 Daily Cost/Mud($): --- Measured Depth(ft): 37 Drilling Days(act.): 8 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 37 Drilling Days(plan): 22 RKB Elevation(ft): 4.00 --- --- --- Proposed TD(ft): 1500 Days On Location: 8 Last BOP Test: --- --- --- Hole Made(ft)/Hrs: 0/0.0 Last Casing: Totals --- --- Average ROP(ft/hr): Next Casing: 6.625 at 30 Working Interest: Well Cost($): --- Personnel: Operator: 3 Contractor: 7 Service: 7 Other: 4 Total: 21 Current Operations: Waiting on equipment due to weather. Planned Operations: Open hole to 9-7/8". Run and cement 6-5/8"conductor Toolpusher: David Griggs. Wellsite Supervisors: Alan Bailey, Randy Baldwin Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 3:00 3.00 37 OPEN Opened hole to 7-1/2"f/25't/37'with full returns.Temp out=52 deg F. 3:00 4:30 1.50 37 CIRC Circulate and clean hole. 4:30 5:00 0.50 37 TRPO PON. 5:00 0:00 19.00 37 WOE Continued to sling loads w/helicopter while wating on 9-7/8"bit. Set up living quarters X on well site. Management Summary 9-7/8"bit in Dutch Harbor-unable to mobilize it due to weather. Comments Open 5 1/2 inch hole to 7 1/2 inch F/25 ft.T/37 ft.with full returns.Temp out 52 degrees. Circulate hole clean. POOH with 7 1/2 inch bit.Slind loads. Install 2 living coridorrs.Waiting on 9 7/8 inch bit that is in Dutch. Bad weather. Rig Information Equipment Problems: Location Condition: Transport: Safety Information Meetings/Drills Time Description Safety 15 Pre-tour safety meetings with both crews. First Aid: Medical: Lost Time Accidents: Days Since LTA: 7 ❑ BOP Test ❑ Crownamatic Check Weather Information Sky Condition: Fog and Wind Visibility: 0.5 Air Temperature: 52.0 degF Bar.Pressure: Wind Speed/Dir: 15/E Wind Gusts: 20 Printed: 09:14 14-Feb-14 RIMBase 7.0.2.114 Page: 1 of 1 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well-Akutan Field: Hot Springs Bay Ve Sect:32 Town:095 Rng: 112W County:Aleutians East State:AK Report No: 9 Report For 18-Jul-10 Operator: City of Akutan Rig: Major LF90 Spud Date: 16-Jul-10 Daily Cost/Mud($): --- Measured Depth(ft): 37 Drilling Days(act.): 9 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 37 Drilling Days(plan): 22 RKB Elevation(ft): 4.00 --- --- --- Proposed TD(ft): 1500 Days On Location: 9 Last BOP Test: --- --- --- Hole Made(ft)/Hrs: 0/0.0 Last Casing: 6.675 at 37 Totals --- --- Average ROP(ft/hr): Next Casing: 6.625 at 30 Working Interest: Well Cost($): --- Personnel: Operator: 2 Contractor: 7 Service: 7 Other: 4 Total: 20 Current Operations: WOC. Installed 6-5/8"riser. Planned Operations: Core ahead 5-1/2"hole to 150'. Toolpusher: David Griggs. Wellsite Supervisors: Randy Baldwin Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 11:30 11.50 37 WOE Waited on 9-7/8"bit from Dutch Harbor delayed due to weather. Worked on equipment X and camps. 11:30 15:00 3.50 37 OPEN Bit arrived on location.MU bit and opened hole to 9-7/8"t/37'with full returns.Temp out=57 deg F. 15:00 15:30 0.50 37 CIRC Circulated hole clean. 15:30 16:00 0.50 37 TRPO POH&LD bit. 16:00 17:00 1.00 37 CASE Ran 33 ft.of 6 5/8 inch casing.Centered casing using PQ rod with XO. 17:00 19:00 2.00 37 CMTP Ran 1-1/4"PVC tremie pipe to 37'.Mixed and pumped 2-1/2 bbls of 13.5 ppg cement. (50%excess.) CIP at 1900. 19:00 21:00 2.00 37 WOC Wait on cement. 21:00 22:00 1.00 37 CMTS Tagged cement 6 ft.down. Performed top job using 1/2 bbl of 13.5 ppg cement through tremie.CIP at 2200. 22:00 0:00 2.00 37 WOC Wait on cement. Management Summary 9-7/8"bit arrived on location at 11:30 hrs. Comments Opened hole to 9-7/8"t/37'with full returns. Ran 33 ft of 6-5/8"20#casing as conductor.Cemented conductor with tremie,WOC&ran top job.WOC. Casing/Tubular Information Type Size Top MD Top TVD Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.675 4 37 COND 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 3 1 B HUGE GT-1 9.875 0 37 4 9.2 80 9 1 150 0 0 0 0 Jets: 18 18 18 Out: 37 Grade: Cutter: 2/2 Dull WT/NO Wear:A Brgs: E Gge: 0 Pull: TD Rig Information Equipment Problems: Location Condition: Transport: Safety Information Meetings/Drills Time Description Safety 15 Pre-tour safety meetings with both crew. First Aid: Medical: Lost Time Accidents: Days Since LTA: 8 ❑ BOP Test ❑ Crownamatic Check Printed: 09:14 14-Feb-14 R/MBase 7.0.2.114 Page: 1 of 1 Daily Drilling Report Geothermal Resource Group II0 Well ID: AGP TG-2 Well Name: Hot Springs Well -Akutan Field: Hot Springs Bay Ve Sect:32 Town:095 Rng: 112W County:Aleutians East State:AK Report No: 10 Report For 19-Jul-10 Operator: City of Akutan Rig: Major LF90 Spud Date: 16-Jul-10 Daily Cost/Mud($): --- Measured Depth(ft): 115 Drilling Days(act.): 10 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 115 Drilling Days(plan): 22 RKB Elevation(ft): 4.00 --- --- --- Proposed TD(ft): 1500 Days On Location: 10 Last BOP Test: --- --- --- Hole Made(ft)/Hrs: 78/14.0 Last Casing: 6.675 at 37 Totals --- Average ROP(ft/hr): 5.57 Next Casing: 6.625 at 30 Working Interest: Well Cost($): Personnel: Operator: 2 Contractor: 7 Service: 4 Other: 4 Total: 17 Current Operations: Took drift shot with MRT-0 deg inc.and 97 deg F.Core ahead f/115't/138'with full returns. Mud temp out 91 deg F. Planned Operations: Continue coring to 150'casing point. Run and cement 4-1/2"HWT casing. Nipple up BOPE. Toolpusher: David Griggs. Wellsite Supervisors: Randy Baldwin Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 4:00 4.00 37 WOC Waited on cement. 4:00 5:00 1.00 37 OTHER Pumped out cellar&tagged cement 1 foot down. Remove PQ rod and x-over from casing. 5:00 9:00 4.00 37 BOPO MU 6-5/8"riser. Re-installed foot clamp and foot. 9:00 10:00 1.00 37 CIRC Conditioned mud to 8.9 ppg. 10:00 0:00 14.00 115 DRIL Core 5-1/2 inch hole f/37't/115'with full returns. Temp in=57 deg F,Temp out=87 deg F. Management Summary Fines in the mud causing core barrel to become sticky. Comments WOC. MU riser&cored 5-1/2"hole U115'. Casing/Tubular Information Type Size Top MD Top TVD Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.675 4 37 COND 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-Jul-10 18:00 at Depth 92 ft Sample from Mud Pits,Type:Low Solids Non-Dispersed 8.70 39 10 57 89 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 ADT 2A0 5.500 37 78 14 5.6 9 37 200 Jets: Out: 157 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) 37 115 37 37 200 Annular Velocity: Drill Collars: 90.7 Drill Pipe: 90.7 Survey Information Survey Meas. Vertical Coordinates Type Depth Inc. Azimuth TVD Closure Section N-S E-W D.L.S. TOTCO 100.0 0.00 0.0 100.0 0.0 0.0 0.000 Rig Information Equipment Problems: Location Condition: Transport: Printed: 09:14 14-Feb-14 R/MBase 7.0.2.114 Page: 1 of 2 KO Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well-Akutan Field: Hot Springs Bay Ve Sect: 32 Town: 095 Rng: 112W County:Aleutians East State:AK Report No: 10 Report For 19-Jul-10 Safety Information Meetings/Drills Time Description Safety 15 Pre-tour safety meetings with both crew. First Aid: Medical: Lost Time Accidents: Days Since LTA: 9 D BOP Test ❑ Crownamatic Check Printed: 09:14 14-Feb-14 RIMBase 7.0.2.114 Page:2 of 2 Daily Drilling Report Geothermal Resource Group 60Well ID: AGP TG-2 Well Name:Hot Springs Well-Akutan Field: Hot Springs Bay W Sect:32 Town:095 Rng: 112W County:Aleutians East State:AK Report No: 11 Report For 20-Jul-10 Operator: City of Akutan Rig: Major LF90 Spud Date: 16-Jul-10 Daily Cost/Mud($): --- Measured Depth(ft): 157 Drilling Days(act.): 11 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 157 Drilling Days(plan): 22 RKB Elevation(ft): 4.00 --- --- --- Proposed TD(ft): 1500 Days On Location: 11 Last BOP Test: --- --- --- Hole Made(ft)/Hrs: 42/11.0 Last Casing: 4.500 at 157 Shoe Test(lbs/gal): 12.00 Totals --- --- Average ROP(ft/hr): 3.82 Next Casing: 3.500 at 600 Working Interest: Well Cost($): --- Personnel: Operator: 2 Contractor: 7 Service: 3 Other: 4 Total: 16 Current Operations: Waited on cement. Removed cement head. Planned Operations: Nipple-up and test BOPE. Toolpusher: David Griggs. Wellsite Supervisors: Randy Baldwin Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 6:30 6.50 138 DRIL Cored 5-1/2"hole f/115'U138'with full returns.Temp out 81 degrees. 6:30 8:00 1.50 138 CIRC Cleaned mud pits&conditioned mud. 8:00 11:30 3.50 148 DRIL Cored f/138't/148'with full returns.Temp out 98 degees. 11:30 12:30 1.00 148 TRPO PON to retrieve core-core dropped from barrel due to fines in pipe. 12:30 13:30 1.00 148 TRPI RIH t/148'. 13:30 14:30 1.00 157 DRIL Cored 5-1/2 inch hole f/148't/157'with full returns. 14:30 15:30 1.00 157 CIRC Circulated&conditioned for casing. Ran drift shot w/MRT. 0.75 inc.&173 deg F BHT. 15:30 16:30 1.00 157 TRPO PON with pipe and core barrel. 16:30 20:00 3.50 157 CASE MU and ran 4-1/2"HWT casing. Tack welded float collar above 1st joint. 20:00 21:00 1.00 157 CASE Circulated casing.Temp out= 144 deg F.MU landing joint with cement head.Tagged bottom&pulled up 2'. 21:00 23:00 2.00 157 CMTP Mixed 3.2 bbls of 13.5 ppg cement(100%excess). Pumped 1 bbl of water ahead,3.2 bbls of cement.Dropped plug&displace with 2.25 bbls of water.Bumped plug and checked float. Float held. 23:00 0:00 1.00 157 WOC Wait on cement. Comments Cored 5-1/2"hole f/115't/157'with full returns.Ran and cemented 4-1/2"HWT casing. Casing/Tubular Information Type Size Top MD Top TVD Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.675 4 37 COND FULL 4.500 3 3 157 157 SURF 5.500 12.00 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 20-Jul-10 12:00 at Depth 148 ft Sample from Mud Pits,Type:Low Solids Non-Dispersed 8.70 40 10 61 81 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 ADT 2A0 5.500 37 120 24 5.0 9 37 200 Jets: Out: 157 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) 115 157 37 37 200 Annular Velocity: Drill Collars: 90.7 Drill Pipe: 90.7 Printed: 09:14 14-Feb-14 R/MBase 7.0.2.114 Page: 1 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well -Akutan Field: Hot Springs Bay Ve Sect: 32 Town: 095 Rng: 112W County:Aleutians East State:AK Report No: 11 Report For 20-Jul-10 Survey Information Survey Meas. Vertical Coordinates Type Depth Inc. Azimuth TVD Closure Section N-S E-W D.L.S. TOTCO 157.0 0.75 Rig Information Equipment Problems: Location Condition: Transport: Safety Information Meetings/Drills Time Description Safety 15 Pre-tour with both crews. First Aid: Medical: Lost Time Accidents: Days Since LTA: 10 ❑ BOP Test ❑ Crownamatic Check Printed: 09:14 14-Feb-14 RIMBase 7.0.2.114 Page:2 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well-Akutan Field: Hot Springs Bay Va Sect:32 Town: 095 Rng: 112W County:Aleutians East State:AK Report No: 12 _ Report For 21-Jul-10 Operator: City of Akutan Rig: Major LF90 Spud Date: 16-Jul-10 Daily Cost/Mud($): --- Measured Depth(ft): 157 Drilling Days(act.): 12 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 157 Drilling Days(plan): 22 RKB Elevation(ft): 4.00 --- --- --- Proposed TD(ft): 1500 Days On Location: 12 Last BOP Test: --- --- --- Hole Made(ft)/Hrs: 0/0.0 Last Casing: 4.500 at 157 Shoe Test(lbs/gal): 12.00 Totals --- --- Average ROP(ft/hr): Next Casing: 3.500 at 600 Working Interest: Well Cost($): --- Personnel: Operator: 2 Contractor: 7 Service: 4 Other: 4 Total: 17 Current Operations: Nippling up BOPE. Planned Operations: Finish nippling up BOPE and test. Perform formation integrity test. Toolpusher: David Griggs. Wellsite Supervisors: Randy Baldwin Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 6:00 6.00 157 WOC Waited on cement. 6:00 8:00 2.00 157 OTHER Broke out cement head and landing joint. 8:00 16:00 8.00 157 BOPO Weld center ring. Nippled up BOPE. 16:00 18:00 2.00 157 BOPT Function tested annular preventer and pneumatic diverter valve.Tested casing to 650 psi.Leak at the thread on wellhead. 18:00 0:00 6.00 157 BOPND Nippled down BOPE and BakerLok'd wellhead. Comments Waited on cement. Nippled up BOPE. Function and pre-tested BOPE-small leak at wellhead. Nippled down BOPE. Casing/Tubular Information Type Size Top MD Top TVD Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.675 4 37 COND FULL 4.500 3 3 157 157 SURF 5.500 12.00 Rig Information Equipment Problems: Location Condition: Transport: Safety Information Meetings/Drills Time Description Safety 15 Pre-tour with both crews. First Aid: Medical: Lost Time Accidents: Days Since LTA: 11 ❑ BOP Test ❑ Crownamatic Check Printed: 09:14 14-Feb-14 R/MBase 7.0.2.114 Page: 1 of 1 Daily Drilling Report Geothermal Resource Group 0 Well ID: AGP TG-2 Well Name: Hot Springs Well-Akutan Field:Hot Springs Bay Vs Sect:32 Town:095 Rng: 112W County:Aleutians East State:AK Report No: 13 Report For 22-Jul-10 Operator: City of Akutan Rig: Major LF90 Spud Date: 16-Jul-10 Daily Cost/Mud($): --- Measured Depth(ft): 173 Drilling Days(act.): 13 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 173 Drilling Days(plan): 22 RKB Elevation(ft): 4.00 --- --- --- Proposed TD(ft): 1500 Days On Location: 13 Last BOP Test: 22-Jul-10 --- --- --- Hole Made(ft)/Hrs: 16/5.0 Last Casing: 4.500 at 157 Shoe Test(lbs/gal): 12.00 Totals --- --- Average ROP(ft/hr): 3.2 Next Casing: 3.500 at 600 Working Interest: Well Cost($): --- Personnel: Operator: 2 Contractor: 7 Service: 4 Other: 4 Total: 17 Current Operations: Cored 3-1/2"hole f/173't/225'with full returns. Planned Operations: Core ahead 3-1/2"hole to 600'. Toolpusher: David Griggs. Welisite Supervisors: Randy Baldwin Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 14:30 14.50 157 BOPNU Nippled up BOPE. 14:30 18:30 4.00 157 BOPT Tested casing,master valve,pneumatic 3-1/8" 3M diverter valve and kill line to 750 psi.Approx 35 lbs/10 minutes bleed off. Ran test plug&tested annular preventer to 750 psi.Tested accumulator and LEL alarms. Tests approved as per inspector Jeff Jones,AOGCC. 18:30 23:30 5.00 173 DRIL RIH. Drill out float collar and shoe track.Cored 3-1/2"hole t/173'with full returns.Temp out 88 degrees. 23:30 0:00 0.50 173 BOPO Circulated hole clean.Closed bag and performed formation integrity test with 8.5#mud in hole to 32 psi. (0.625 psi/12 ppg equivalent.) Comments Nippled up BOPE.Tested casing,master valve,diverter valves,annular prevent,and kill line to 750 psi. Tested accumulator and LEL alarms. Drill out float collar and shoe track.Cored 3-1/2"hole to 173'with full returns.Temp out 88 degrees. Performed FIT. Casing/Tubular Information Type Size Top MD Top TVD Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.675 4 37 COND FULL 4.500 3 3 157 157 SURF 5.500 12.00 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-Jul-10 17:00 at Depth 157 ft Sample from Mud Pits,Type:Low Solids Non-Dispersed 8.50 32 9 57 81 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 ATCOP Hobic 6 3.830 157 16 0.5 32.0 9 37 160 Jets: Out: 223 Grade: Cutter: 4/3 Dull WT/NO Wear: Brgs: Gge: 0 Pull: TQ 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) 157 173 32.0 37 37 160 Annular Velocity: Drill Collars: 332.6 Drill Pipe: 332.6 Rig Information Equipment Problems: Location Condition: Transport: Printed: 09:14 14-Feb-14 R/MBase 7.0.2.114 Page: 1 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well -Akutan Field: Hot Springs Bay Ve Sect: 32 Town: 095 Rng: 112W County:Aleutians East State:AK Report No: 13 Report For 22-Jul-10 Safety Information Meetings/Drills Time Description Safety 15 Pre-tour with both crews, BOP 120 First Aid: Medical: Lost Time Accidents: Days Since LTA: 12 ✓❑ BOP Test ❑ Crownamatic Check Printed: 09:14 14-Feb-14 RIMBase 7.0.2.114 Page:2 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well-Akutan Field: Hot Springs Bay VE Sect:32 Town:095 Rng: 112W County:Aleutians East State:AK Report No: 14 Report For 23-Jul-10 Operator: City of Akutan Rig: Major LF90 Spud Date: 16-Jul-10 Daily Cost/Mud($): --- Measured Depth(ft): 281 Drilling Days(act.): 14 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 281 Drilling Days(plan): 22 RKB Elevation(ft): 4.00 --- --- --- Proposed TD(ft): 1500 Days On Location: 14 Last BOP Test: 22-Jul-10 --- --- --- Hole Made(ft)/Hrs: 108/14.5 Last Casing: 4.500 at 157 Shoe Test(lbs/gal): 12.00 Totals --- --- Average ROP(ft/hr): 7.45 Next Casing: 3.500 at 600 Working Interest: Well Cost($): --- Personnel: Operator: 2 Contractor: 7 Service: 4 Other: 4 Total: 17 Current Operations: Cored 3-1/2"hole f/281't/312'with full returns. Planned Operations: Core ahead 3-1/2"hole to 600'. Toolpusher: David Griggs. Wellsite Supervisors: Randy Baldwin Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 6:30 6.50 223 DRIL Cored 3-1/2"hole f/157't/223'with full returns.Temp out=94 deg F. 6:30 7:00 0.50 223 TRPO POH out due to high torque. 7:00 9:00 2.00 223 TRPI MU new bit and reamer,checked LELs in cellar.RIH t/223'. 9:00 10:00 1.00 241 DRIL Cored 3-1/2"hole f/223't/241'with full returns.Temp out=94 deg F. 10:00 10:30 0.50 241 TRPO Worked stuck tube.POH to 160'.Well started flowing.Conditioned mud to 8.7 ppg. Finished POH. 10:30 11:00 0.50 241 CIRC RIH to 241'. 11:00 11:30 0.50 241 SURV Circulated hole.Ran drift shot with MRT at 241'. 2.25 deg inc, 234 deg F. 11:30 15:30 4.00 256 DRIL Cored 3-1/2"hole f/241't1256'with full returns.Temp out=94 deg F. 15:30 16:00 0.50 256 TRPO POH due to stuck tube. Barite causing cake inside of rods. 16:00 17:30 1.50 256 OTHER Pressure wash barite from inside of rods and outside of core barrel.Condition mud to 8.6 ppg. 17:30 18:30 1.00 256 TRPI RIH to 256'. 18:30 21:00 2.50 271 DRIL Cored 3-1/2"hole f/256't/271'with full returns.Temp out=94 deg F. Check LELs in cellar. 21:00 22:00 1.00 271 TRPO POH for stuck tube. 22:00 22:30 0.50 271 REPR Repaired inner tube. X 22:30 23:30 1.00 271 TRPI RIH t/271'. 23:30 0:00 0.50 281 DRIL Cored 3-1/2"hole f/271't/281'with full returns.Temp out=94 deg F. Ran MRT at 281',273 deg F. Comments Cored 3-1/2"hole f/157't/241'with full returns.Tripped for bit. Well flowed while tripping.Cored 3-1/2"hole f/241't/281'with full returns. Casing/Tubular Information Type Size Top MD Top TVD Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.675 4 37 COND FULL 4.500 3 3 157 157 SURF 5.500 12.00 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-Jul-10 17:00 at Depth 256 ft Sample from Mud Pits,Type:Low Solids Non-Dispersed 8.60 36 9.5 80 98 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 ATCOP Hobic 6 3.830 157 124 13.5 9.2 1200 9 37 200 Jets: Out: 223 Grade: Cutter: 4/3 Dull WI/NO Wear: Brgs: Gge: 0 Pull: TQ Printed: 09:14 14-Feb-14 RIMBase 7.0.2.114 Page: 1 of 2 Daily Drilling Report Geothermal Resource Group 0 Well ID: AGP TG-2 Well Name: Hot Springs Well -Akutan Field: Hot Springs Bay Ve Sect: 32 Town: 095 Rng: 112W County:Aleutians East State:AK Report No: 14 Report For 23-Jul-10 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) 173 223 1200 37 37 150 Annular Velocity: Drill Collars: 444.9 Drill Pipe: 444.9 Comments: Trip for bit#5 at 223'. 223 281 1200 37 37 150 Annular Velocity: Drill Collars: 444.9 Drill Pipe: 444.9 Survey Information Survey Meas. Vertical Coordinates Type Depth Inc. Azimuth TVD Closure Section N-S E-W D.L.S. TOTCO 241.0 2.25 Rig Information Equipment Problems: Location Condition: Transport: Safety Information Meetings/Drills Time Description Safety 15 Pre-tour with both crews. First Aid: Medical: Lost Time Accidents: Days Since LTA: 13 ❑ BOP Test ❑ Crownamatic Check Printed: 09:14 14-Feb-14 R/MBase 7.0.2.114 Page:2 of 2 Daily Drilling Report Geothermal Resource Group 60Well ID: AGP TG-2 Well Name: Hot Springs Well-Akutan Field: Hot Springs Bay VE Sect:32 Town:095 Rng: 112W County:Aleutians East State:AK Report No: 15 Report For 24-Jul-10 Operator: City of Akutan Rig: Major LF90 Spud Date: 16-Jul-10 Daily Cost/Mud($): --- Measured Depth(ft): 470 Drilling Days(act.): 15 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 470 Drilling Days(plan): 22 RKB Elevation(ft): 4.00 --- --- --- Proposed TD(ft): 1500 Days On Location: 15 Last BOP Test: 22-Jul-10 --- --- --- Hole Made(ft)/Hrs: 189/19.5 Last Casing: 4.500 at 157 Shoe Test(lbs/gal): 12.00 Totals --- --- Average ROP(ft/hr): 9.69 Next Casing: 3.500 at 600 Working Interest: Well Cost($): --- Personnel: Operator: 2 Contractor: 7 Service: 4 Other: 4 Total: 17 Current Operations: Openen bag&finished POH with core barrel.RIH t/20'with water swivel while repairing core barrel.RIH with bit, reamer, and core barrel to 470'.Circulated and conditioned mud.Bottoms-up temp=136 deg F. Cored t/499 ft. Planned Operations: Core ahead to 600 ft. Toolpusher: David Griggs. Wellsite Supervisors: Randy Baldwin Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 5:00 5.00 312 DRIL Cored 3-1/2"hole f/281 t/312'with full returns.Temp out=104 deg F Ran MRT= 212 deg F. 5:00 6:30 1.50 322 DRIL Cored 3-1/2"hole f/312't/322'with full returns.Temp out=94 deg F Ran MRT=216 deg F 6:30 10:30 4.00 339 DRIL Cored 3-1/2"hole f/322't/339'with full returns.Temp out=116 deg F Ran MRT=180 deg F.Checked LELs in cellar 0800. 10:30 12:00 1.50 370 DRIL Cored 3-1/2"hole f/339't/370'with full returns.Temp out=90 deg F 12:00 12:30 0.50 370 SURV Ran drift shot with MRT at 370'. 1.75 deg inc, 226 deg F. 12:30 13:40 1.17 400 DRIL Cored 3-1/2"hole f/370't/400'with full returns.Temp out= 117 deg F Ran MRT=163 deg F. 13:40 15:30 1.83 430 DRIL Cored 3-1/2"hole f/400't/430'with full returns.Temp out= 105 deg F Ran MRT=171 deg F. 15:30 18:40 3.17 469 DRIL Cored 3-1/2"hole f/430't/469'with full returns.Temp out= 103 deg F Ran MRT=234 deg F. 18:40 20:00 1.33 470 DRIL Cored 3-1/2"hole f/469't/470'with full returns.Temp out=93 deg F Checked LELs in cellar. 20:00 21:00 1.00 470 TRPO Circ.and clean hole.POH due to high torque and pressure.At 13'the well began flowing. Inner tube became stuck part way up in core barrel. 21:00 0:00 3.00 470 KILL Hot water camed up annulus.Closed annular preventer.Opened 3 inch manual X diverter valve.Opened 3 inch pneumatic diverter valve, Well flowed at an estimated 120 gals/min.Closed pnematic diverter valve.Mixed bar to 10 ppg mud and killed well. Comments Cored 3-1/2"hole f/281't/470'with full returns. Ran MRTs approx every 30 ft. POH due to high torque and pressure.Well began flowing with bit at 13'.Mixed and pump 10 ppg mud and killed well. Casing/Tubular Information Type Size Top MD Top TVD Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.675 4 37 COND FULL 4.500 3 3 157 157 SURF 5.500 12.00 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 24-Jul-10 17:00 at Depth 460 ft Sample from Mud Pits,Type:Low Solids Non-Dispersed 8.50 36 10 88 115 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 ADT 8DM 3.870 223 109 19.5 5.6 9 70 200 Jets: Out:613 Grade: Cutter: 2/2 Dull WT/NO Wear:A Brgs: X Gge: 0 Pull: TD Printed: 09:14 14-Feb-14 RIMBase 7.0.2.114 Page: 1 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well -Akutan Field: Hot Springs Bay Ve Sect: 32 Town:095 Rng: 112W County:Aleutians East State:AK Report No: 15 Report For 24-Jul-10 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) 281 479 1100 1200 70 70 200 Annular Velocity: Drill Collars: 629.2 Drill Pipe: 629.2 Comments: Using both mud pumps. Rig Information Equipment Problems: Location Condition: Transport: Safety Information Meetings/Drills Time Description Safety 15 Pre-tour with both crews, First Aid: Medical: Lost Time Accidents: Days Since LTA: 14 ❑ BOP Test ❑ Crownamatic Check Printed: 09:14 14-Feb-14 RIMBase 7.0.2.114 Page:2 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well-Akutan Field: Hot Springs Bay Va Sect:32 Town:095 Rng: 112W County:Aleutians East State:AK Report No: 16 _ Report For 25-Jul-10 Operator: City of Akutan Rig: Major LF90 Spud Date: 16-Jul-10 Daily Cost/Mud($): --- Measured Depth(ft): 503 Drilling Days(act.): 16 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 503 Drilling Days(plan): 22 RKB Elevation(ft): 4.00 --- --- --- Proposed TD(ft): 1500 Days On Location: 16 Last BOP Test: 22-Jul-10 --- --- --- Hole Made(ft)/Hrs: 33/3.5 Last Casing: 4.500 at 157 Shoe Test(lbs/gal): 12.00 Totals --- --- Average ROP(ft/hr): 9.43 Next Casing: 3.500 at 600 Working Interest: Well Cost($): --- Personnel: Operator: 2 Contractor: 7 Service: 4 Other: 4 Total: 17 Current Operations: Wait on repair parts. Planned Operations: Make repairs and core ahead. Toolpusher: David Griggs. Wellsite Supervisors: Randy Baldwin Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 2:30 2.50 470 TRPI Opened bag. POH with core barrel and inner tube.MU core barrel and RIH T/470'. Hole stayed full. 2:30 6:00 3.50 503 DRIL Cored 3-1/2"hole f/470't/503'with full returns. Temp out=130 deg F. 6:00 8:00 2.00 503 OTHER Attempted to pull tube. Inner barrel stuck. Conditioned mud.Attempted to pull tube again. Checked LELs in cellar at 08:00. 8:00 12:00 4.00 503 REPR Attempted to POH.Jaws in head would not grip pipe.Disassembled head and X discovered damage.Ordered parts to fix. 12:00 0:00 12.00 503 WOE Waited on parts.Circulated hole. Temp out=122 deg F. Checked LELs in cellar at X 20:00. Comments RIH&cored 3-1/2"hole f/470't/503'with full returns. Inner core barrel stuck.Attempted to POH.Jaws in head broken. Waited on parts. Casing/Tubular Information Type Size Top MD Top ND Bottom MD Bottom ND Hole Section Avg OH Diam LOT FULL 6.675 4 37 COND FULL 4.500 3 3 157 157 SURF 5.500 12.00 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 25-Jul-10 17:00 at Depth 503 ft Sample from Mud Pits,Type:Low Solids Non-Dispersed 8.50 35 10 88 125 Bit/BHAIWorkstring 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 ADT 8DM 3.870 223 142 23 6.2 9 70 250 Jets: Out: 613 Grade: Cutter: 2/2 Dull WT/NO Wear:A Brgs: X Gge: 0 Pull: TD 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) 470 503 6.0 1100 1200 70 70 250 Annular Velocity: Drill Collars: 629.2 Drill Pipe: 629.2 Comments: Using both mud pumps. Rig Information Equipment Problems: 5 of the 7 nitorgen impellers that hold down jaws on chuck are bad. Location Condition: Transport: Printed: 09:14 14-Feb-14 R/MBase 7.0.2.114 Page: 1 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well-Akutan Field: Hot Springs Bay Vs Sect: 32 Town:095 Rng: 112W County:Aleutians East State:AK Report No: 16 Report For 25-Jul-10 Safety Information Meetings/Drills Time Description Safety 15 Pre=tour with both crews. First Aid: Medical: Lost Time Accidents: Days Since LTA: 15 ❑ BOP Test D Crownamatic Check Weather Information Sky Condition: Visibility: Air Temperature: Bar.Pressure: Wind Speed/Dir: / Wind Gusts: Printed: 09:14 14-Feb-14 RIMBase 7.0.2.114 Page:2 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well-Akutan Field: Hot Springs Bay Ve Sect:32 Town:095 Rng: 112W County:Aleutians East State:AK Report No: 17 Report For 26-Jul-10 Operator: City of Akutan Rig: Major LF90 Spud Date: 16-Jul-10 Daily Cost/Mud($): --- Measured Depth(ft): 503 Drilling Days(act.): 17 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 503 Drilling Days(plan): 22 RKB Elevation(ft): 4.00 --- --- --- Proposed TD(ft): 1500 Days On Location: 17 Last BOP Test: 22-Jul-10 --- --- --- Hole Made(ft)/Hrs: 0/0.0 Last Casing: 4.500 at 157 Shoe Test(lbs/gal): 12.00 Totals --- --- Average ROP(ft/hr): Next Casing: 3.500 at 600 Working Interest: Well Cost($): --- Personnel: Operator: 2 Contractor: 7 Service: 4 Other: 4 Total: 17 Current Operations: Waited on parts.Circulated hole. Temp out= 128 deg F. Planned Operations: Make repairs on rig and core ahead to 600'. Toolpusher: David Griggs. Wellsite Supervisors: Randy Baldwin Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 0:00 24.00 503 REPR Waited on parts.Circulated hole. Temp out=128 deg F. Checked LELs in cellar at X 06:00 and 20:00. Comments Waited on parts.Circulated hole. Temp out=128 deg F. Casing/Tubular Information Type Size Top MD Top TVD Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.675 4 37 COND FULL 4.500 3 3 157 157 SURF 5.500 12.00 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 26-Jul-10 17:00 at Depth 503 ft Sample from Mud Pits,Type:Low Solids Non-Dispersed 8.50 34 10 90 128 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 ADT 8DM 3.870 223 142 23 0.0 0.0 0 0 0 9 35 200 Jets: Out: 613 Grade: Cutter: 2/2 Dull WT/NO Wear:A Brgs: X Gge: 0 Pull: TD Rig Information Equipment Problems: 5 of the 7 nitorgen impellers that hold down jaws on chuck are bad.Jaws wont grip the pipe. Location Condition: Transport: Safety Information Meetings/Drills Time Description Safety 15 Pre-tour with both crews. First Aid: Medical: Lost Time Accidents: 1 Days Since LTA: 16 Accident Description: Person holding 36 inch pipe wrench to tighten water swivel,pulled his muscle in his right shoulder. ❑ BOP Test ❑ Crownamatic Check Weather Information Sky Condition: Visibility: Air Temperature: Bar.Pressure: Wind Speed/Dir: / Wind Gusts: Printed: 09:14 14-Feb-14 R/MBase 7.0.2.114 Page: 1 of 1 Daily Drilling Report Geothermal Resource Group litWell ID: AGP TG-2 Well Name: Hot Springs Well-Akutan Field: Hot Springs Bay Vs Sect:32 Town:095 Rng: 112W County:Aleutians East State:AK Report No: 18 Report For 27-Jul-10 Operator: City of Akutan Rig: Major LF90 Spud Date: 16-Jul-10 Daily Cost/Mud($): --- Measured Depth(ft): 503 Drilling Days(act.): 18 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 503 Drilling Days(plan): 22 RKB Elevation(ft): 4.00 --- --- --- Proposed TD(ft): 1500 Days On Location: 18 Last BOP Test: 22-Jul-10 --- --- --- Hole Made(ft)/Hrs: 0/0.0 Last Casing: 4.500 at 157 Shoe Test(lbs/gal): 12.00 Totals --- --- Average ROP(ft/hr): Next Casing: 3.500 at 600 Working Interest: Well Cost($): --- Personnel: Operator: 2 Contractor: 7 Service: 4 Other: 4 Total: 17 Current Operations: Waited on parts.Circulated hole. Temp out= 118 deg F. Planned Operations: Make repairs on rig and core ahead to 600'. Toolpusher: David Griggs. Wellsite Supervisors: Randy Baldwin Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 0:00 24.00 503 REPR Waited on parts.Circulated hole. Temp out=118 deg F. Rig parts made it to Dutch X Harbor.Helocopper went to get parts,engine light came on.Check LELs in cellar at 06:00 and 20:00. Comments Waited on parts.Circulated hole. Temp out=118 deg F. (Temp coming down due to winds across sump.) Casing/Tubular Information Type Size Top MD Top TVD Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.675 4 37 COND FULL 4.500 3 3 157 157 SURF 5.500 12.00 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 27-Jul-10 17:00 at Depth 503 ft Sample from Mud Pits,Type:Low Solids Non-Dispersed 8.50 34 10 75 115 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 ADT 8DM 3.870 223 142 23 9 35 175 Jets: Out: 613 Grade: Cutter: 2/2 Dull WT/NO Wear:A Brgs:X Gge: 0 Pull: TD Rig Information Equipment Problems: 5 of the 7 nitorgen impellers that hold down jaws on chuck are bad.Jaws wont grip the pipe. Location Condition: Transport: Safety Information Meetings/Drills Time Description Safety 15 Pre-tour with both crews. First Aid: Medical: Lost Time Accidents: Days Since LTA: 17 ❑ BOP Test ❑ Crownamatic Check Printed: 09:14 14-Feb-14 RIMBase 7.0.2.114 Page: 1 of 1 ��. Daily Drilling Report Geothermal Resource Group \Y Well ID: AGP TG-2 Well Name: Hot Springs Well-Akutan Field: Hot Springs Bay Vs Sect:32 Town:095 Rng: 112W County:Aleutians East State:AK Report No: 19 Report For 28-Jul-10 Operator: City of Akutan Rig: Major LF90 Spud Date: 16-Jul-10 Daily Cost/Mud($): --- Measured Depth(ft): 613 Drilling Days(act.): 19 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 613 Drilling Days(plan): 22 RKB Elevation(ft): 4.00 --- --- --- Proposed TD(ft): 1500 Days On Location: 19 Last BOP Test: 22-Jul-10 --- --- --- Hole Made(ft)/Hrs: 110/9.5 Last Casing: 4.500 at 157 Shoe Test(lbs/gal): 12.00 Totals --- --- Average ROP(ft/hr): 11.58 Next Casing: 3.500 at 600 Working Interest: Well Cost($): --- Personnel: Operator: 2 Contractor: 7 Service: 4 Other: 4 Total: 17 Current Operations: RIH with 3 1/2 inch casing t/603 ft.Cemented casing,bump plug.CIP at 0430.WOC. Planned Operations: Test cement.Test BOPs. Pick up NQ rods. Toolpusher: David Griggs. Wellsite Supervisors: Randy Baldwin Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 8:00 8.00 503 REPR Waited on parts from Dutch Harbor. Circulated hole. Temp out= 100 deg F Check X LEL levels in cellar. 8:00 10:30 2.50 523 DRIL Install parts, Cored 3-1/2"hole f/503't/523'with full returns. Temp in 77 deg f.Temp out= 107 deg F. MRT=169 deg F. 10:30 12:00 1.50 553 DRIL Cored 3-1/2"hole f/523't/553'with full returns. Temp out=80 deg F. 12:00 12:30 0.50 553 SURV Ran drift shot with MRT at 553'. 3.75 deg inc, 187 deg F 12:30 14:00 1.50 583 DRIL Cored 3-1/2"hole f/553't/583'with full returns. Temp out= 100 deg F. MRT=169 deg F. 14:00 15:00 1.00 593 DRIL Cored 3-1/2"hole f/583 t/593' lost all returns at 590 ft.. MRT=169 deg F. 15:00 16:00 1.00 593 OTHER Let well heat up. 16:00 17:00 1.00 593 KILL Ran MRT with lubricator.Well started flowing. Let well flow for 10 minutes to get water sample.Close in and kill well. Had 203 deg F at surface with about 1 bbl/min flow. MRT=359 deg F. 17:00 20:00 3.00 613 DRIL Cored 3-1/2"hole f/593 t/613' with no returns.Check LEL levels in cellar. 20:00 21:30 1.50 613 WOO Wait on orders. X 21:30 22:00 0.50 613 KILL Pump 8.5 ppg mud down drill pipe,and 8.9 ppg mud down annulus. 22:00 0:00 2.00 613 TRPO POH with rods and core barrel with bit. Comments Waited on parts.Cored 3-1/2"hole f/503 t/593' lost all returns at 590 ft.Ran MRT. Well started flowing. Let well flow for 10 minutes and obtained a water sample.Closed in and killed well. Had 203 deg F at surface with about 1 bbl/min flow. MRT=359 deg F.Cored 3-1/2"hole f/593 t/613' with no returns.POH. Casing/Tubular Information Type Size Top MD Top TVD Bottom MD Bottom ND Hole Section Avg OH Diam LOT FULL 6.675 4 37 COND FULL 4.500 3 3 157 157 SURF 5.500 12.00 FULL 3.500 -3 604 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 28-Jul-10 15:00 at Depth 590 ft Sample from Mud Pits,Type:Low Solids Non-Dispersed 8.50 36 10 78 110 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 ADT 8DM 3.870 223 252 32.5 7.8 1100 9 70 120 Jets: Out: 613 Grade: Cutter: 2/2 Dull WT/NO Wear:A Brgs: X Gge: 0 Pull: TD Printed: 09:14 14-Feb-14 R/MBase 7.0.2.114 Page: 1 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well -Akutan Field: Hot Springs Bay Vz Sect: 32 Town: 095 Rng: 112W County:Aleutians East State:AK Report No: 19 Report For 28-Jul-10 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) 503 613 1100 1200 70 70 100 Annular Velocity: Drill Collars: 629.2 Drill Pipe: 629.2 Comments: Lost returns at 590 ft. Rig Information Equipment Problems: 5 of the 7 nitorgen impellers that hold down jaws on chuck are bad.Jaws wont grip the pipe. Location Condition: Transport: Safety Information Meetings/Drills Time Description Safety 15 Pre-tour with both crews. First Aid: Medical: Lost Time Accidents: Days Since LTA: 18 ❑ BOP Test Ei Crownamatic Check Printed: 09:14 14-Feb-14 RIMBase 7.0.2.114 Page:2 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well-Akutan Field: Hot Springs Bay Va Sect: 32 Town: 095 Rng: 112W County:Aleutians East State:AK Report No: 20 Report For 29-Jul-10 Operator: City of Akutan Rig: Major LF90 Spud Date: 16-Jul-10 Daily Cost/Mud($): --- Measured Depth(ft): 613 Drilling Days(act.): 20 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 613 Drilling Days(plan): 22 RKB Elevation(ft): 4.00 --- --- --- Proposed TD(ft): 1500 Days On Location: 20 Last BOP Test: 22-Jul-10 --- --- --- Hole Made(ft)/Hrs: 0/0.0 Last Casing: 3.500 at 604 Totals --- --- Average ROP(ft/hr): Next Casing: 1.660 at 1,500 Working Interest: Well Cost($): --- Personnel: Operator: 2 Contractor: 7 Service: 4 Other: 4 Total: 17 Current Operations: Tested BOPs. Planned Operations: Finish testing BOPs. Core ahead. Toolpusher: David Griggs. Wellsite Supervisors: Randy Baldwin Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 2:30 2.50 613 TRPI RIH with 603'of 3-1/2"7.7#casing with float collar 10 ft.up. Nipple down 3M pneumatic valve. 2:30 4:30 2.00 613 CMTP Pumped 1 bbl of water ahead. mixed and pump 3.9 bbls of 13.5 ppg cement,dropped plug,and displaced with 5.5 bbls of water. Bumped plug and checked float-float held. No returns throughout job. CIP 0430. 4:30 11:30 7.00 613 WOC Waited on cement.Washed up cement equipment.MU 1000 ft.of N rods in 20 ft. lengths. 11:30 12:00 0.50 613 OTHER Pumped 1 bbl of water to wash down annulus at 60 psi. 12:00 12:30 0.50 613 BOPT Tested casing U 750 psi. 12:30 13:15 0.75 613 CMTS Mixed and circulated 2.8 bbls of 13.5 ppg cement as top job. Started at 80 psi, dropped to 40 psi,and built up to 130 psi. CIP 13:30. Flushed stack. 13:15 13:30 0.25 613 TRPO POOH with 10 ft. landing joint. Closed master valve and wing valve.Monitored pressure through kill line. 13:30 22:00 8.50 613 WOC Waited on cement. Nippled up 3M pneumatic valve. 22:00 0:00 2.00 613 BOPT Tested master valve,outside wing valve,and kill line to 200 psi.and again to to 750 psi.Master valve leaked. Removed pitcher nipple and wash inside of master valve with pressure washer. Comments Ran and cement 603 ft.of 3-1/2"casing. CIP @ 04:30. WOC.Washed annulus with fresh water and performed top job.CIP @ 13:30 WOC. Nlppled up BOP. Began testing BOPE. Casing/Tubular Information Type Size Top MD Top TVD Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.675 4 37 COND FULL 4.500 3 3 157 157 SURF 5.500 12.00 FULL 3.500 -3 604 Survey Information Survey Meas. Vertical Coordinates Type Depth Inc. Azimuth TVD Closure Section N-S E-W D.L.S. TOTCO 370.0 1.75 TOTCO 469.0 2.25 TOTCO 553.0 3.75 Rig Information Equipment Problems: Location Condition: Transport: Safety Information Meetings/Drills Time Description Safety 15 Pre-tour with both crews. First Aid: Medical: Lost Time Accidents: Days Since LTA: 19 ❑ BOP Test ❑ Crownamatic Check Printed. 09:14 14-Feb-14 RIMBase 7.0.2.114 Page: 1 of 1 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well-Akutan Field: Hot Springs Bay Va Sect: 32 Town: 095 Rng: 112W County:Aleutians East State:AK Report No: 21 Report For 30-Jul-10 Operator: City of Akutan Rig: Major LF90 Spud Date: 16-Jul-10 Daily Cost/Mud($): --- Measured Depth(ft): 613 Drilling Days(act.): 21 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 613 Drilling Days(plan): 22 RKB Elevation(ft): 4.00 --- --- --- Proposed TD(ft): 1500 Days On Location: 21 Last BOP Test: 22-Jul-10 --- --- --- Hole Made(ft)/Hrs: 0/0.0 Last Casing: 3.500 at 604 Totals --- Average ROP(ft/hr): Next Casing: 1.660 at 1,500 Working Interest: Well Cost($): --- Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 4 Total: 18 Current Operations: Nippled down and inspected BOPs. Planned Operations: Continue inspecting BOPs. Install and test BOPs. Toolpusher: David Griggs. Wellsite Supervisors: Randy Baldwin, Dan Darnell Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 5:00 5.00 613 BOPT Attempedt to pressure test BOPS. Still leaking. 5:00 8:00 3.00 613 TRPI Changed over to NQ rods and RIH t/300 ft. 8:00 8:30 0.50 613 COOL Pump 2 bbls of water down drill pipe. 8:30 12:00 3.50 613 TRPO Attempted to close hydrill. Accumulator pump not working. Disasembled gear box on pump. Teeth missing on gears. Ordered replacement. 12:00 16:00 4.00 613 BOPT Attempted to test BOPs,still leaking. No surface leaks visible. 16:00 19:00 3.00 613 CMTS Mixed 1 sack of cement and attempted to squeeze 3-1/2 inch annulus. 19:00 0:00 5.00 613 CMTS Mixed 1 sack of cement with 3%CaCl2 and attempted to squeeze annulus. Comments Attempted to test BOPE. RIH 11300'.Attempted to test with water.Gear box on accumulator failed. POH.Attempted to test master valve, kill line and diverter valves.Squeezed 3-1/2"annulus with cement. Casing/Tubular Information Type Size Top MD Top ND Bottom MD Bottom ND Hole Section Avg OH Diam LOT FULL 6.675 4 37 COND FULL 4.500 3 3 157 157 SURF 5.500 12.00 FULL 3.500 -3 604 Rig Information Equipment Problems: Gears on accumulator have numerous missing teeth. Replacement parts have been ordered and shipped. Location Condition: Transport: Safety Information Meetings/Drills Time Description Safety 15 Pre-tour with both crews, First Aid: Medical: Lost Time Accidents: Days Since LTA: 20 ❑ BOP Test ❑ Crownamatic Check Printed: 09:14 14-Feb-14 RIMBase 7.0.2.114 Page: 1 of 1 Daily Drilling Report Geothermal Resource Group 0 Well ID: AGP TG-2 Well Name: Hot Springs Well-Akutan Field: Hot Springs Bay Va Sect: 32 Town: 095 Rng: 112W County:Aleutians East State:AK : Report No: 22 _ Report For 31-Jul-10 Operator: City of Akutan Rig: Major LF90 Spud Date: 16-Jul-10 Daily Cost/Mud($): --- Measured Depth(ft): 613 Drilling Days(act.): 22 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 613 Drilling Days(plan): 22 RKB Elevation(ft): 4.00 --- --- --- Proposed TD(ft): 1500 Days On Location: 22 Last BOP Test: 31-Jul-10 --- --- --- Hole Made(ft)/Hrs: 0/0.0 Last Casing: 3.500 at 604 Totals --- Average ROP(ft/hr): Next Casing: 1.660 at 1,500 Working Interest: Well Cost($): --- Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 4 Total: 18 Current Operations: Ran in the hole and tagged TOO @ 581'. Cleaned out cement f/581'to 583'before the string plugged. POH&checked tools. RIH @ 06:00 hrs. Planned Operations: Clean out float and test casing. Core 20'below shoe and perform leakoff test. Toolpusher: David Griggs. Wellsite Supervisors: Dan Darnell Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 3:00 3.00 613 WOC Waited on cement, 3:00 8:00 5.00 613 BOPND Nippled down BOPE,(note,Cellar was tested for LEL/H2s before nippling down,0 X Ppm) 8:00 10:00 2.00 613 BOPO Cleaned and checked all API ring,flange faces, and inspect well head seal assembly, X 10:00 15:00 5.00 613 BOPNU Installed new 0 ring's on test plug,checked seal area and installed. Replaced API X rings on all BOPE. Repaired accumalator and tested. 15:00 18:00 3.00 613 BOPT Pretested and changed out washed valves on mud pump#1 X 18:00 19:30 1.50 613 BOPT Ran test plug and tested between the Master valve and pneumatic valve at 250 psi and 750 psi for 30 min each.Good tests. 19:30 20:30 1.00 613 BOPT Tested between master valve and 3-1/8"manual at 250 psi 750 psi for 30 minutes each. Good tests. 20:30 22:00 1.50 613 BOPNU Nippled up annular preventer and function tested . Installed test plug and tested annular preventer at 250 psi and 750 psi.Good tests. 22:00 0:00 2.00 613 TRPI Made up 3.062"F6M core bit#6 on NQ 2.75 pipe and RIH Comments Waited on cement. Nippled down BOPE and cleaned all flange faces. Replaced API rings. Nippled up and tested BOPE-tests were successful. Made up NQ tools and RIH. Casing/Tubular Information Type Size Top MD Top ND Bottom MD Bottom ND Hole Section Avg OH Diam LOT FULL 6.675 4 37 COND FULL 4.500 3 3 157 157 SURF 5.500 12.00 FULL 3.500 -3 604 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 31-Jul-10 22:00 804.00 32 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 FORDIF F6M 3.062 613 Jets: Out: 671 Grade: Cutter: / Dull / Wear: Brgs: Gge: Pull: PR Rig Information Equipment Problems: Replaced parts on accumulator and tested, Changed out washed valves on pump#1. Location Condition: muddy Transport: Printed: 09:14 14-Feb-14 RIMBase 7.0.2.114 Page: 1 oft Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well-Akutan Field: Hot Springs Bay VE Sect: 32 Town: 095 Rng: 112W County:Aleutians East State:AK Report No: 22 Report For 31-Jul-10 Safety Information Meetings/Drills Time Description Safety 30 Safety meeting held with both crews First Aid: Medical: Lost Time Accidents: Days Since LTA: 21 111 BOP Test ❑ Crownamatic Check Weather Information Sky Condition: Rain Visibility: Air Temperature: 62.0 degF Bar.Pressure: Wind Speed/Dir: 37/ Wind Gusts: Printed: 09:14 14-Feb-14 R/MBase 7.0.2.114 Page:2 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well-Akutan Field: Hot Springs Bay VE Sect:32 Town:095 Rng: 112W County:Aleutians East State:AK Report No: 23 Report For 01-Aug-10 Operator: City of Akutan Rig: Major LF90 Spud Date: 16-Jul-10 Daily Cost/Mud($): --- Measured Depth(ft): 623 Drilling Days(act.): 23 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 623 Drilling Days(plan): 22 RKB Elevation(ft): 4.00 --- --- --- Proposed TD(ft): 1500 Days On Location: 23 Last BOP Test: 31-Jul-10 --- --- --- Hole Made(ft)/Hrs: 10/0.5 Last Casing: 3.500 at 604 Totals --- --- Average ROP(ft/hr): 20.0 Next Casing: 1.660 at 1,500 Working Interest: Well Cost($): --- Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 4 Total: 18 Current Operations: Circ and cooled well.Mix and spotted 1 bbl of 13.5 lb cmt at @ 623'. POH t/343'and squeezed.CIP @ 02:30.WOC. Planned Operations: Clean out cement to 623'.Core 2.75"hole to 643'and conduct leakoff test. Drill ahead. Toolpusher: David Griggs. Wellsite Supervisors: Dan Darnell Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 0:30 0.50 613 OTHER Switch over to NQ, 0:30 4:30 4.00 613 TRPI Tripped in hole.Tagged and cleaned out cement stringer f/400't/581'.Tagged TOC @ 581'. 4:30 5:00 0.50 613 CMTD Cleaned out wiper plug and cement f/581'U 583'. 5:00 8:00 3.00 613 TRPO POH due to cement stuck in core barrel.Ran in hole to 583' 8:00 8:30 0.50 613 BOPT Tested 3.5 HQ casing to 750 psi for 10 min.Test good. 8:30 9:30 1.00 613 CIRC Circ and conditioned hole @ 583'. 9:30 13:30 4.00 613 CMTD Cleaned out float collar @ 592'. Cleaned out cement and shoe to 603'. 13:30 15:00 1.50 613 CMTD Drilled cement to 613'. 15:00 17:30 2.50 613 TRPI POH for repairs.The upper latch body was unscrewed from lower latch assy,Ran in X hole to 613' 17:30 18:00 0.50 623 DRIL Core 2.98"hole f/613't/623'. X 18:00 19:30 1.50 623 FIT POH to shoe and conducted leak-off test using 8.4 ppg fluid. Leaked off at 50 psi and 7 gallons. Bled down to 20 psi.Fracture gradient =.52 psi/ft. 19:30 21:00 1.50 623 CIRC Circ bottoms up @ 623'. 21:00 22:00 1.00 623 OTHER Mixed and spotted 50 vis gel pill @ 623'. 22:00 0:00 2.00 623 FIT POH into shoe&waited 30 min.Conducted leak off test#2.Pumped 3 gallons and pressured up to 60 psi and stopped. Pumped 1 gallon and pressure spiked to 150 psi, bled off to 100 psi.Pumped 1 gallon and pressure spiked to 250 psi but bled down to 65 psi and held. Results inconclusive. Prepared to perform squeeze. Comments Cleaned out float and shoe and drilled ahead 20 feet. Performed leakoff test with resultant 0.52 gradient. Set gel pill on bottom and performed a second leakoff test-estimated gradient at 0.54 but pressure reading were difficult to interpret. Perpared to perform cement squeeze of shoe. Casing/Tubular Information Type Size Top MD Top TVD Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.675 4 37 COND FULL 4.500 3 3 157 157 SURF 5.500 12.00 FULL 3.500 -3 604 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 01-Aug-10 08:00 804.00 32 7 0 75 95 Bit/BHAIWorkstring 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 FORD/ F6M 3.062 613 10 0.5 20.0 Jets: Out: 671 Grade: Cutter: / Dull / Wear: Brgs: Gge: Pull: PR Printed: 09:14 14-Feb-14 R/MBase 7.0.2.114 Page: 1 of 2 66 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well-Akutan Field: Hot Springs Bay Ve Sect: 32 Town: 095 Rng: 112W County:Aleutians East State:AK Report No: 23 Report For 01-Aug-10 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) 613 623 20.0 30.0 Comments: Core w/2.75 f/613'to 623' Rig Information Equipment Problems: Elastomers melted on inner barrel. Location Condition: muddy Transport: Safety Information Meetings/Drills Time Description Safety 30 Safety meeting held with both crews First Aid: Medical: Lost Time Accidents: Days Since LTA: 22 E BOP Test E Crownamatic Check Weather Information Sky Condition: Cloudy/Rain Visibility: 0.25 Air Temperature: 46.0 degF Bar.Pressure: Wind Speed/Dir: 25/N Wind Gusts: 45 Printed: 09:14 14-Feb-14 RIMBase 7.0.2.114 Page:2 of 2 Daily Drilling Report Geothermal Resource Group litWell ID: AGP TG-2 Well Name: Hot Springs Well-Akutan Field: Hot Springs Bay Va Sect:32 Town:095 Rng: 112W County:Aleutians East State:AK Report No: 24 Report For 02-Aug-10 Operator: City of Akutan Rig: Major LF90 Spud Date: 16-Jul-10 Daily Cost/Mud($): --- Measured Depth(ft): 661 Drilling Days(act.): 24 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 661 Drilling Days(plan): 22 RKB Elevation(ft): 4.00 --- --- --- Proposed TD(ft): 1500 Days On Location: 24 Last BOP Test: 31-Jul-10 --- --- --- Hole Made(ft)/Hrs: 38/5.5 Last Casing: 3.500 at 604 Totals --- --- Average ROP(ft/hr): 6.91 Next Casing: 1.660 at 1,500 Working Interest: Well Cost($): --- Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 4 Total: 18 Current Operations: Core 2.98"hole f/661't/671',POH for bit. RIH.451'@ 06:00 hr's. Planned Operations: RIH. Run Pressure/Temperature survey and drill ahead. Toolpusher: David Griggs. Wellsite Supervisors: Dan Darnell Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 2:30 2.50 623 CMTPL Circ and cooled well @ 623',temp out= 109 deg F.Mixed 1 bbl of 13.51b cement and spotted @ 623'.POH to 363'and filled hole.Closed annular and squeezed. Squeezed a total of 25 gals of cement from inital pressure of 65 psi to a final pressure of 500 psi. Held for 15 min and bled off pressure.CIP @ 02:30. 2:30 10:30 8.00 623 WOC WOC 8 hours.Opened well and circulated core rods clean @ 363'. 10:30 11:00 0.50 623 TRPI RIH and tagged TOC @ 503'. 11:00 16:00 5.00 623 CMTD Cleaned out firm cement f/503't/623'. 16:00 16:30 0.50 623 CIRC Circulated and cooled hole @ 623'. 16:30 18:00 1.50 643 DRIL Cored 2.98"hole f/623't/643'. 18:00 18:30 0.50 643 EVAL Ran MRT at 640'. BHT=216 deg F 18:30 19:00 0.50 643 FIT Spotted 30 gal,50 vis gel pill @ 643'.POH to 553'and circ excess mud out of hole. Performed timed leak-off test with 8.4 ppg fluid in hole at a rate of 0.75 gal a min. Pressure broke over @ 180 psi.Fracture gradient =.74 psi/ft.' 19:00 20:00 1.00 643 WASH Circ&conditioned hole f/603'to 643'. 20:00 0:00 4.00 643 DRIL Cored 2.98"hole f/643't/661' Comments Squeezed shoe with 25 gallons of cement. WOC. Cleaned out cement and drilled ahead to 643'. Performed timed leakoff test with 8.4 ppg mud to 180 psi surface pressure-gradient=.74 psi/ft. Cored f/643't/661'. Casing/Tubular Information Type Size Top MD Top TVD Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.675 4 37 COND FULL 4.500 3 3 157 157 SURF 5.500 12.00 FULL 3.500 -3 604 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 02-Aug-10 22:00 8.40 32 7 0 72 110 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 FORDIF F6M 3.062 613 48 6 8.0 10.0 600 1200 8 598 596 Jets: Out:671 Grade: Cutter: / Dull / Wear: Brgs: Gge: Pull: PR 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) 623 661 5.0 10.0 300 400 1100 1200 69 70 460 Annular Velocity: Drill Collars: 598.0 Drill Pipe: 629.0 Miscellaneous Drilling Parameters Hook Loads(lbs): Off Bottom Rotate: Pick Up: Slack Off: Drag Avg/Max: / Printed: 09:14 14-Feb-14 R/MBase 7.0.2.114 Page: 1 of 2 11)0 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well-Akutan Field: Hot Springs Bay Ve Sect: 32 Town:095 Rng: 112W County:Aleutians East State:AK Report No: 24 Report For 02-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 623 661 Formation Name: Lithology: Rig Information Equipment Problems: Problems with light plant getting hot Location Condition: muddy Transport: Safety Information Meetings/Drills Time Description Safety 30 Safety meeting held with both crews First Aid: Medical: Lost Time Accidents: Days Since LTA: 23 ❑ BOP Test ❑ Crownamatic Check Weather Information Sky Condition: Rain Visibility: 0.25 Air Temperature: 47.0 degF Bar.Pressure: Wind Speed/Dir: 0/ Wind Gusts: Printed: 09:14 14-Feb-14 RIMBase 7.0.2.114 Page:2 of 2 Daily Drilling Report Geothermal Resource Group 'NI Well ID: AGP TG-2 Well Name: Hot Springs Well-Akutan Field: Hot Springs Bay Ve Sect:32 Town:095 Rng: 112W County:Aleutians East State:AK Report No: 25 Report For 03-Aug-10 Operator: City of Akutan Rig: Major LF90 Spud Date: 16-Jul-10 Daily Cost/Mud($): --- Measured Depth(ft): 713 Drilling Days(act.): 25 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 713 Drilling Days(plan): 22 RKB Elevation(ft): 4.00 --- --- --- Proposed TD(ft): 1500 Days On Location: 25 Last BOP Test: 31-Jul-10 --- --- --- Hole Made(ft)/Hrs: 52/10.0 Last Casing: 3.500 at 604 Totals --- --- Average ROP(ft/hr): 5.2 Next Casing: 1.660 at 1,500 Working Interest: Well Cost($): --- Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 4 Total: 18 Current Operations: Cored 2.98"hole f/713't/733'.Twisted off and left 30 of fish,inner barrel,and 700 ft of wire line in hole. Planned Operations: Attempt to recover fish in hole, Toolpusher: David Griggs. Wellsite Supervisors: Dan Darnell Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 2:30 2.50 671 DRIL Cored 2.98"hole f/661'11671'-full returns/no core recovery. 2:30 3:00 0.50 671 CIRC Circ @ 671'. X 3:00 3:30 0.50 671 OTHER Ran MRT,297 deg F. 3:30 5:30 2.00 671 TRPO Tripped for bit f/671'.Changed Bit#6. X 5:30 7:00 1.50 671 TRPI RIH in hole t/671',checked cellar for LEL. X 7:00 10:00 3.00 671 OTHER Rigged up and ran Pressure/Temperature survey to 658'. Max Temp(BHT)=300 deg F. 10:00 12:00 2.00 678 DRIL Cored 2.98"hole f/671'to 678'with full returns/no core recovery. Inner barrel stuck in X rods. 12:00 15:00 3.00 678 TRPO POH and recovered inner barrel. X 15:00 15:30 0.50 681 DRIL Cored 2.98"hole f/678 t/681'with full returns/no core recovery. Pulled tube and only X recovered the latch head. 15:30 17:00 1.50 681 TRPO POH to core barrel. Repaired inner barrel.Changed bit#7. X 17:00 18:30 1.50 681 TRPI Tripped in hole to 681'. X 18:30 19:00 0.50 681 CIRC Circ©681'.Checked cellar for LEL. X 19:00 0:00 5.00 713 DRIL Cored 2.98"hole f/681't/713'with full returns. Comments Cored f/661'11671'. Tripped for bit. Ran Pa survey to 658'. Cored f/671'11678'. POH to recover and repair inner core barrel. Cored f/678't/713'. Casing/Tubular Information Type Size Top MD Top TVD Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.675 4 37 COND FULL 4.500 3 3 157 157 SURF 5.500 12.00 FULL 3.500 -3 604 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 03-Aug-10 21:00 8.40 37 0 80 115 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 FORM/ F6M 3.062 613 58 8.5 6.8 10.0 300 1200 8 70 596 Jets: Out: 671 Grade: Cutter: / Dull / Wear: Brgs: Gge: Pull: PR 7 1 FORDI/ F6M 3.062 671 10 2.5 4.0 5.0 300 1200 8 35 460 Jets: Out: 681 Grade: Cutter: / Dull / Wear: Brgs: Gge: Pull: 8 1 FORDI/ F6M 3.032 681 42 5 8.4 10.0 300 1200 8 35 305 Jets: Out: 733 Grade: Cutter: / Dull / Wear: Brgs: Gge: Pull: Printed. 09:14 14-Feb-14 R/MBase 7.0.2.114 Page: 1 of 2 Daily Drilling Report Geothermal Resource Group 0 Well ID: AGP TG-2 Well Name: Hot Springs Well -Akutan Field: Hot Springs Bay Ve Sect: 32 Town:095 Rng: 112W County:Aleutians East State:AK Report No: 25 Report For 03-Aug-10 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) 671 713 6.0 10.0 200 250 1100 1200 35 35 305 Comments: Cored 2.98"hole ft 678'to 713' 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 661 713 Formation Name: Lithology: Rig Information Equipment Problems: Light plant Location Condition: muddy Transport: Safety Information Meetings/Drills Time Description Safety 30 Safety meeting held with both crews First Aid: Medical: Lost Time Accidents: Days Since LTA: 24 D BOP Test 11 Crownamatic Check Weather Information Sky Condition: Rain Visibility: Air Temperature: 47.0 degF Bar.Pressure: Wind Speed/Dir: / Wind Gusts: Printed: 09:14 14-Feb-14 R/MBase 7.0.2.114 Page:2 of 2 Daily Drilling Report Geothermal Resource Group 1$ Well ID: AGP TG-2 Well Name: Hot Springs Well-Akutan Field:Hot Springs Bay V2 Sect:32 Town:095 Rng: 112W County:Aleutians East State:AK Report No: 26 Report For 04-Aug-10 Operator: City of Akutan Rig: Major LF90 Spud Date: 16-Jul-10 Daily Cost/Mud($): --- Measured Depth(ft): 793 Drilling Days(act.): 26 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 793 Drilling Days(plan): 22 RKB Elevation(ft): 4.00 --- --- --- Proposed TD(ft): 1500 Days On Location: 26 Last BOP Test: 31-Jul-10 --- --- --- Hole Made(ft)/Hrs: 80/11.5 Last Casing: 3.500 at 604 Totals --- --- Average ROP(ft/hr): 6.96 Next Casing: 1.660 at 1,500 Working Interest: Well Cost($): --- Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 4 Total: 18 Current Operations: Cored NQ hole f/793't/833'with 2-3 bph mud loss. POH due to stuck barrel. Planned Operations: Retrieve inner core barrel that is stuck. Toolpusher: David Griggs. Wellsite Supervisors: Dan Darnell Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 4:00 4.00 733 DRIL Cored 2.98"hole f/713't/733'with full returns and full recovery. 4:00 5:30 1.50 733 FISH Inner barrel was dropped and became stuck while retrieving.Attempted to retrieve tube X using wireline overshot-no success. 5:30 8:00 2.50 733 FISH Cut and released wire line and pulled out of hole with NQ rod. Core rod had twisted off X at 703'. Fish in hole comprised of inner core tube,over shot and latch assembly,700' of wire line with the outer core barrel attached and 30'of core rod. Estimated TOF @ 690'. 8:00 15:00 7.00 733 FISH Fabricated wireline spear and RIH. Tagged wire line @ 92'.Worked spear in line and X pulled out of hole.Cut and recovered wire line,latch assembly and inner core tube. Made up 2-1/2"tubing spear and RIH. Tagged top of fish @ 690'. Worked spear into top of fish& POH with fish.Made up 3.032"New Bit#8 and RIH t/733'. 15:00 16:00 1.00 733 SURV Ran wire line survey @ 710'with MRT.Survey=3/4 deg. BHT=320 deg F 16:00 16:30 0.50 733 OTHER Made up PIT tool and ran in hole to bottom. Result=300 psi BHP and 320.3 deg F BHT. 16:30 0:00 7.50 793 DRIL Cored 3.032"hole f/733't/793'. Began losing 2 to 3 bbls/hr @ 746'. Comments Cored NQ hole f/713't/733'. Dropped inner barrel and twisted off. Retrieved fish with wireline spear and taper tap. Ran in hole with new bit and performed temperature evaluation. Cored NQ hole f/733't/793'. Casing/Tubular Information Type Size Top MD Top TVD Bottom MD Bottom ND Hole Section Avg OH Diam LOT FULL 6.675 4 37 GOND FULL 4.500 3 3 157 157 SURF 5.500 12.00 FULL 3.500 -3 604 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 04-Aug-10 22:00 8.40 38 75 90 Bit/BH _AIWorkstring 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 8 1 FORD/ F6M 3.032 681 42 9 4.7 5.0 300 1200 8 35 275 Jets: Out: 733 Grade: Cutter: / Dull / Wear: Brgs: Gge: Pull: 9 1 ADT 2A0 3.032 733 60 7.5 8.0 15.0 300 1200 8 35 285 Jets: Out: 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) 713 793 10.0 20.0 300 400 1100 1200 35 70 285 Comments: Cored 3.032"hole f/713'to 793'losing around 2 to3 bbls an hr Printed: 09:14 14-Feb-14 RIMBase 7.0.2.114 Page: 1 of 2 Daily Drilling Report Geothermal Resource Group IWell ID: AGP TG-2 Well Name: Hot Springs Well-Akutan G Field: Hot Springs Bay Ve Sect: 32 Town: 095 Rng: 112W County:Aleutians East State:AK Report No: 26 Report For 04-Aug-10 Survey Information Survey Meas. Vertical Coordinates Type Depth Inc. Azimuth TVD Closure Section N-S E-W D.L.S. TOTCO 710.0 0.75 TOTCO 803.0 1.25 Rig Information Equipment Problems: Light plant Location Condition: muddy Transport: Safety Information Meetings/Drills Time Description Safety 30 Safety meeting held with both crews First Aid: Medical: Lost Time Accidents: Days Since LTA: 25 ❑ BOP Test ❑ Crownamatic Check Weather Information Sky Condition: Rain Visibility: 2.5 Air Temperature: 44.0 degF Bar.Pressure: Wind Speed/Dir: / Wind Gusts: Printed: 09:14 14-Feb-14 RIMBase 7.0.2.114 Page:2 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well-Akutan Field: Hot Springs Bay VE Sect:32 Town:095 Rng: 112W County:Aleutians East State:AK Report No: 27 Report For 05-Aug-10 Operator: City of Akutan Rig: Major LF90 Spud Date: 16-Jul-10 Daily Cost/Mud($): --- Measured Depth(ft): 833 Drilling Days(act.): 27 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 833 Drilling Days(plan): 22 RKB Elevation(ft): 4.00 --- --- --- Proposed TD(ft): 1500 Days On Location: 27 Last BOP Test: 31-Jul-10 --- --- --- Hole Made(ft)/Hrs: 40/4.0 Last Casing: 3.500 at 604 Totals --- --- Average ROP(ft/hr): 10.0 Next Casing: 1.660 at 1,500 Working Interest: Well Cost($): --- Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 4 Total: 18 Current Operations: Continued to let well stand the first 12 hr pressure and temperature log.Made up PT tools and began logging entire well bore.Well began flowing near end of first test.Mize CaCI brine to 9.5 ppg. Killed well and displaced well bore @ 06:00 hr's. Planned Operations: Finish displacing well with 9.5#brine and resume logging. Toolpusher: David Griggs. Wellsite Supervisors: Dan Darnell Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 4:00 4.00 833 DRIL Cored 3.032"hole f/793't/833'. Lost 2-3 bbl/hr. 4:00 5:30 1.50 833 TRPO Unable to retrieve inner barrel. POH-left core barrel and 10'of NQ in hole. X 5:30 12:00 6.50 833 FISH Made up 2.50"spear and RIH.Tagged top of fish @ 810'.Worked spear into top of fish X and POH.Layed out fish and inspected tools and equipment. RR bit#9 and RIH to 833'. 12:00 13:30 1.50 833 CIRC Circ and cooled well. Mixed and displaced well bore with 9.1 #CaCI brine.Stopped circulating @ 13:30 hrs. 13:30 0:00 10.50 833 TEST Waiting on well to heat up for 12 hrs prior to pressure and temperature logging. Comments Cored NQ hole f/793't1833'w/2-3 bph loss. Twisted off and left 23'fish in hole. RIH&retrieved fish. Circulated and conditioned wellbore for logging to 9.1#with CaCI brine. Waited on well to heat up before logging. Casing/Tubular Information Type Size Top MD Top TVD Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.675 4 37 COND FULL 4.500 3 3 157 157 SURF 5.500 12.00 FULL 3.500 -3 604 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 05-Aug-10 22:00 8.40 36 75 90 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 9 1 ADT 2A0 3.032 733 100 11.5 8.7 15.0 300 1200 8 35 325 Jets: Out: 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) 793 833 5.0 10.0 300 400 1100 1200 35 .70 325 Comments: Cored 3.032"hole f/793'to 833'.losing 2 to 3 bbl an hr, Rig Information Equipment Problems: Light plant Location Condition: muddy Transport: Printed: 09:14 14-Feb-14 RIMBase 7.0.2.114 Page: 1 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well -Akutan Field: Hot Springs Bay Va Sect: 32 Town: 095 Rng: 112W County:Aleutians East State:AK Report No: 27 Report For 05-Aug-10 Safety Information Meetings/Drills Time Description Safety 30 Safety meeting held with both crews First Aid: Medical: Lost Time Accidents: Days Since LTA: 26 ❑ BOP Test ❑ Crownamatic Check Weather Information Sky Condition: Clear/cloudy Visibility: Air Temperature: Bar.Pressure: Wind Speed/Dir: / Wind Gusts: Printed: 09:14 14-Feb-14 RIMBase 7.0.2.114 Page:2 of 2 Daily Drilling Report Geothermal Resource Group litWell ID: AGP TG-2 Well Name:Hot Springs Well-Akutan Field: Hot Springs Bay Vs Sect:32 Town:095 Rng: 112W County:Aleutians East State:AK Report No: 28 Report For 06-Aug-10 Operator: City of Akutan Rig: Major LF90 Spud Date: 16-Jul-10 Daily Cost/Mud($): --- Measured Depth(ft): 833 Drilling Days(act.): 28 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 833 Drilling Days(plan): 22 RKB Elevation(ft): 4.00 --- --- --- Proposed TD(ft): 1500 Days On Location: 28 Last BOP Test: 31-Jul-10 --- --- --- Hole Made(ft)/Hrs: 0/0.0 Last Casing: 3.500 at 604 Totals --- --- Average ROP(ft/hr): Next Casing: 1.660 at 1,500 Working Interest: Well Cost($): --- Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 4 Total: 18 Current Operations: Continued Temperature/Pressure buildup. Planned Operations: Continue Temperature/Pressure buildup for next log run at 07:45 hrs. Follow on with third log run. Toolpusher: David Griggs. Wellsite Supervisors: Dan Darnell Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 1:30 1.50 833 TEST Let well heat up for down hole temperature survey's 1:30 5:30 4.00 833 TEST Opened well&began Pressure/Temperature logging. Initial stop at 50'and 100', followed by 20'stops to TD. 5:30 7:45 2.25 833 TEST Well began flowing.Mixed and displaced well bore with 9.5#CaICI brine.Circulated 14 minutes. Last circ time @ 07:44 hrs. 7:45 19:45 12.00 833 TEST Allow 12 hour Temperature/Pressure buildup. 19:45 23:45 4.00 833 TEST Ran Pressure/Temperature log as per previous test. 23:45 0:00 0.25 833 TEST Allow Temperature/Pressure buildup. Comments Allowed P/T buildup and began logging. Well flowed at last stop. Killed well with 9.6#brine and pulled tool. Waited on buildup prior to running P/T log. Ran P/T logs. Waited on buildup for next test. Casing/Tubular Information Type Size Top MD Top TVD Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.675 4 37 COND FULL 4.500 3 3 157 157 SURF 5.500 12.00 FULL 3.500 -3 604 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 06-Aug-10 22:00 9.60 27 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) 833 833 Comments: Mixed mud to 9.5#Cal Cloride brine and displace well bore Rig Information Equipment Problems: Light plant Location Condition: muddy Transport: Safety Information Meetings/Drills Time Description Safety 30 Safety meeting held with both crews First Aid: Medical: Lost Time Accidents: Days Since LTA: 27 ❑ BOP Test ❑ Crownamatic Check Printed: 09:14 14-Feb-14 RIMBase 7.0.2.114 Page: 1 of 1 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well-Akutan Field:Hot Springs Bay VE Sect:32 Town:095 Rng: 112W County:Aleutians East State:AK Report No: 29 Report For 07-Aug-10 Operator: City of Akutan Rig: Major LF90 Spud Date: 16-Jul-10 Daily Cost/Mud($): --- Measured Depth(ft): 833 Drilling Days(act.): 29 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 833 Drilling Days(plan): 22 RKB Elevation(ft): 4.00 --- --- --- Proposed TD(ft): 1500 Days On Location: 29 Last BOP Test: 31-Jul-10 --- --- --- Hole Made(ft)/Hrs: 0/0.0 Last Casing: 3.500 at 604 Totals --- --- Average ROP(ft/hr): Next Casing: 1.660 at 1,500 Working Interest: Well Cost($): --- Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 4 Total: 18 Current Operations: POH to shoe @ 603'. Flowed well. Planned Operations: Kill well&lay out NQ rod. Run 1.66"tubing and hang @ surface. Nipple down and begin demobilizing. Toolpusher: David Griggs. Wellsite Supervisors: Dan Darnell Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 7:30 7.50 833 TEST Allowed temperature buildup for logs. 7:30 11:30 4.00 833 TEST Ran Pressure/Temperature logs-20'stops f/100'to TD. BHT=328 deg F 11:30 17:30 6.00 833 TEST Allowed temperature buildup for logs. 17:30 0:00 6.50 833 TEST Ran Pressure/Temperature logs-20'stops from 100'to TD. BHT=330 deg F. Comments Performed Pressure/Temperature logs at the 24 hour and 36 hour mark. Casing/Tubular Information Type Size Top MD Top ND Bottom MD Bottom ND Hole Section Avg OH Diam LOT FULL 6.675 4 37 COND FULL 4.500 3 3 157 157 SURF 5.500 12.00 FULL 3.500 -3 604 Mud Information % Gels Temp Mud Density Vis PV YP Fiit. Cake pH/ES Solids Oil Water Sand LGS Chlor. Cal. 10s 10m 30m In Out Loss 07-Aug-10 22:00 9.50 65 113 Rig Information Equipment Problems: Light plant Location Condition: muddy Transport: Safety Information Meetings/Drills Time Description Safety 30 Safety meeting held with both crews First Aid: Medical: Lost Time Accidents: Days Since LTA: 28 ❑ BOP Test ❑ Crownamatic Check Weather Information Sky Condition: cloudy Visibility: Air Temperature: Bar.Pressure: Wind Speed/Dir: / Wind Gusts: 75 Printed: 09:14 14-Feb-14 R/MBase 7.0.2.114 Page: 1 of 1 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well-Akutan Field: Hot Springs Bay Va Sect:32 Town:095 Rng: 112W County:Aleutians East State:AK Report No: 30 Report For 08-Aug-10 Operator: City of Akutan Rig: Major LF90 Spud Date: 16-Jul-10 Daily Cost/Mud($): --- Measured Depth(ft): 833 Drilling Days(act.): 30 Well Bore: Original Well Bore AFE No. AFE($) Actual($) Vertical Depth(ft): 833 Drilling Days(plan): 22 RKB Elevation(ft): 4.00 --- --- --- Proposed TD(ft): 1500 Days On Location: 30 Last BOP Test: 31-Jul-10 --- --- --- Hole Made(ft)/Hrs: 0/0.0 Last Casing: 1.660 at 818 Totals --- --- Average ROP(ft/hr): Next Casing: Working Interest: Well Cost($): --- Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 4 Total: 18 Current Operations: Waiting on daylight. Planned Operations: Load out and move rig. Toolpusher: David Griggs. Wellsite Supervisors: Dan Darnell Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 11:00 11.00 833 TEST Pulled NQ rod to shoe and allowed well to flow. Well flowed at aproximately 6 bph with max temperature of 216 deg F on blooie line. 11:00 15:00 4.00 833 CIRC Killed well w/cold water. 15:00 15:30 0.50 833 TRPI RIH t/833'. 15:30 16:00 0.50 833 CIRC Mixed and displaced 9.6#CaCI brine throughout wellbore @ 833'. 16:00 18:00 2.00 833 TRPO POH and layed out NQ 2.75"rods. 18:00 19:00 1.00 833 OTHER Picked up and loaded V-Door w/1-1/4"tubing. 19:00 21:00 2.00 833 CASE Made up 1-1/4"check valve on 1.66"tubing.Ran 39 joints/819'of 1.66"tubing and hung off bottom. Nippled down BOP and installed and tightened well head flange. Installed 1-1/4"tubing valve. Comments Allowed well to flow. Killed well and layed down core rod. Made up 1.66"tubing and ran to 818'. Hung off bottom and nippled down BOPE. Well secured with valve in place. Casing/Tubular Information Type Size Top MD Top TVD Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.675 4 37 COND FULL 4.500 3 3 157 157 SURF 5.500 12.00 FULL 3.500 -3 604 HNG DN 1.660 -1 818 OPEN 2.980 Rig Information Equipment Problems: Light plant Location Condition: muddy Transport: Safety Information Meetings/Drills Time Description Safety 30 Safety meeting held with both crews First Aid: Medical: Lost Time Accidents: Days Since LTA: 29 ❑ BOP Test ❑ Crownamatic Check Weather Information Sky Condition: Partly Cloudy/Rain Visibility: Air Temperature: Bar.Pressure: Wind Speed/Dir: / Wind Gusts: 25 Printed: 09:14 14-Feb-14 RIMBase 7.0.2.114 Page: 1 of 1 V fTi /o FEB 192014 AKUTAN AOGOC UNIMAK ISLAND :i' 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, iltve1 it Mary Tesche Assistant City Administrator City of Akutan 907.777.1643 `orb - c,�I Davies, Stephen F (DOA) / O - 67 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 0 / O -07 Schwartz, Guy L (DOA) c ( b - O-7 E From: Hermann Scanlan <akutanadmin@gci.net> Sent: Thursday, December 12,2013 9:43 AM To: Schwartz,Guy L(DOA) Cc: 'Mayor-City of Akutan,Joe Bereskin';'Dianne Woodruff'; raymann@rma-cg.com Subject: AOGCC Bond Request Mr.Schwartz, The City of Akutan has completed the closure of two geothermal test wells in Hot Springs bay Valley of Akutan.We provided you with abandonment reports for the two wells,and the completed forms 10-47 on 14 October 2013. It is our understanding that your review of the reports and documentation is complete and that the City can now process a request for the release of its$200,000 cash bond. Would you please let us know what actions are required to complete this important transaction, and when we might expect to see the release of these funds? Your support is much appreciated in this request.... Tuna 1 .... ....._... . . RECEIVED STATE OF ALASKA OCT 14 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND 1191GCC 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 ofAkutanAban 9/14/2013 " 210071 3.Address: 6.Date Spudded: 13.API Number: 3380 C Street,Suite 205,Anchorage,AK 99503-3952 7/16/2010 • 50-295-20002-00-00 ' ' 4a.Location of Well(GovernmerSt- ntal Section): 6 c((lully 7.Date TD Reached: 14.Well Name and Number: 25 Surface: i 325 ;5 ,S32,T69S,R112W.SM • 8/5/2010 • Hot Springs Well/2 ' • Top of Productive Horizon: 8.KB(ft above MSL): 83.5 15.Field/Pool(s): 2,3-5'E,590'S,S32,T69S,R112W.SM GL(ft above MSL): 77 ' Hot ay Valley Total Depth: 9.Plug Back Depth(MD+TVD): AK _la�-, altc/er fine 2,'E,590'S,S32,T69S,R112W.SM N/A 6z'C 6.e I.<t1ci,( ,A!,/L../L' 4b.Location of Well(State Base Plane Coordinates,NAD 27): 4frI Icy( 10.Total Depth(MD+TVD): 16.Property Designation: 'S Surface: x- .5312kI,2256490.T y-5 •5422/8 44' Zone- 8 833'+833' Fee Agent Corporation TPI: x- 531250 y- 56490 Zone- 8 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 531250 y- 56490 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 GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD F.I PULLED 6.625 20 K55 0 33 0 33 9.875 Tremie w/13.5#Type 2 Premiu 0 4.5 11.2 4130 3 157 3 157 5.5 13.5#Type 2 Premium w/30% 0 3.5 8.69 4130 3 603 3 603 3.87 13.5#Type 2 Premium w/30% 0 24.Open to production or injection? Yes ] NoRyt If Yes,list each 25. TUBING RECORD interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Foot valve at end of 1.66"tubing-tubing can only be circulated from surface. 1.66 818 0(hung from wellhead) At , 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. :�="'-----r DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED r 603-623 1 bbl of 13.5#Type 2 premium cement w/30% ten.-' 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(torr): Press. 24-Hour Rate - 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 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. ,9 ti l z-/�S `i j MIMS 'OCT 15 20'3 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? 2 Yes LI 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 208'.Performed leakoff Alluvium at 620'to 1.3 gradient with no leakoff. Well was airlifted at TD and formation Akutan fluid samples were obtained. Formation at total depth: 31. List of Attachments: Mud loos and pressure/temperature logs. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact:GL rscastih13a�i• Printed Name: Y` ti 4M �,• SG Title: ry A�., �Jµaj Q01- �J Signatur JAL � _ Phone: 0.1-/ "1LF � '1Sicr Date: OM/9_0(3 11 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 MC 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 MC 25.071. Geothermal Resource Group TAPPING THE EARTH'S ENERGY I* Hot Springs Well/TG-2 • Arrived on Akutan Island September 5th, 2013 and began moving equipment to the Hot Springs TG-2 well site. • Completed moving in the equipment on September 6th, 2013 and began setting up for the abandonment. Released pressure from wellhead and attempted to circulate, encountered pump problems and shut down for the day. 4 }i#1 -S -- w 1 4 ;r Figure 1-TG-2 set up to circulate through tubing and out through valves(x2)on the annulus. • September 7`h, 2013 performed pump repairs, circulated with cold water, attempted to pump cement. Pump began kicking back,flushed wellbore with fresh water. • September 8th, 2013 replaced faulty check valve, pumped 44 cu. ft(120%of wellbore volume) of 13.3 ppg TC-Geolite class B premium cement. Cement returned to surface with around 5 gal back. Immediately performed a 12 cu. ft. squeeze into annulus using 13.3 ppg TC-Geolite class B premium cement. Shut in for the night. . - _ --- if loh, \ . ,+rI B Figure 2-TG-2 setup to pump directly into annulus and perform squeeze. Geothermal Resource Group TAPPING THE EARTH'S ENERGY • September 9th, 2013 returned to TG-2 site, cement had fallen in annulus and tubing. Performed 8 cu. ft.top job#1. Shut in well and began moving equipment to South Elbow Well TG-4. • Returned to TG-2 on September 13th, cement had fallen to 23 ft. in tubing and approximately 144 ft. in the annulus. Performed top job#2 with 13.3 ppg TC-Geolite class B premium cement with acceptable returns at surface—used no retardant and shut in for the night. • Returned on September 14th, 2013 and found firm cement at surface. Cut off wellhead 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. 1.66" OD Tubing cemented in place A 4.5"OD Casing 6.675 OD Casing ,..41010/ Figure 3-Firm cement at surface,tubing cemented in place,and cut 3 ft.below grade. 6.675"OD casing- 4 4.5"OD casing- 3.5"OD casing- 1.66"OD casing- Figure 4—Note that the 3.5"casing is below the level of the 4.5"casing,due to being set with a landing joint. d ell I hi Si 0 Geothermal TH'SResource Group TAPPING THE EARENERGY ot ., ^�tiAA?4Np1NM1 , 1 .4,,.. 6 M - .,Z ti t .../ t. lifi Figure 5—After wellhead was cut off,depth was measured to confirm 3 ft.below grade. Cs" its ..Z.A.' _ •1,.. .;,..,:-..'.:., .7"`,,--.1.4 `�. 4. r 1 . . Figure 6—A 4"plate was welded on over the structural casing and tubing. Geothermal Resource Group TAPPING THE EARTH'S ENERGY s1 Fcp., t q M Asit k'',44.41:. Figure 7—After plate was welded on,the name plate with Permit to Drill#was welded. • September 15th, 2013 cellar culvert was removed and cellar was filled. n Figure 8—TG-2 site after cellar was removed and filled(facing S-SW). Akutan TG-2 "Hot Springs"Well I INF OI` 6-5/8" Conductor at 37' to Fully Cemented 210- 07 4-Y2" 0.25 WT Casing at 157' Fully Cemented / k,,> M I& Is:X343 / p_ 3 c b,..i / 3-Y2" 0.25WT Casing at 603' 4 Ln Loss Zone at 746 _ 3.01" Open Hole to 833" _ 1.660" 2.4ppf Tubing, Hung from Surface to 818' 1 \, v r. k r e• �L tit11110011111010"13 .,. '-"'1-�� .4.w.:....:7:4,..- ,-,11,',-;....* i � i.:1101,_. uo., ... 4., q1 4Z \ I 40.11:40, ' . 1--41 tv. � '''.#4,40.,..• F I, 1 v� /� f , it�' ,: : 4 v` / Y gyp, Initially when opening the 1.5" valve, water was released under some pressure. • vaelowsiot syr; ,. r „?, oor-- ono ynk+ ; 's 4410'�16""`�„ yam £. r�r*` • 41".. f u '_ �L�;/jG � y ./.yy�p ►�fd T r. - s/..• J. . '4-- }_ �Pir9_�. After a few minutes the water then turned to pure vapor and steam, this was the 1.66" OD tubing, after about 60-90 minutes the tubing was evacuated and the check valve in place at the shoe was working and eventually discharged and had only small steam puffs coming out. � . . , WI * a After that the bud plugs were removed from the flange, opening up the well's annulus to the surface andsteam was blowing out similar to the tubing. —aim 'r-r 1 4111.1.7 , -....,,,,, _, N. 11sa4a., 2,1e ( Age 00001.11, x;41:' -,:\ _ tit -- ... .......----r* After hooking into the 1.66" tubing with the grout pump and appropriate check valves, and 2" Sch. 80 piping, cold water was injected into the wellbore to kill it. Annulus was also eventually temporarily killed and two valves were placed over the holes in the annulus 1" valve and a %2" valve (pictured on the right side). In this picture, cold water is being circulated through the 1.66" tubing and up through the annulus through the two aforementioned valves (notice that they are both open—and no steam—the well is now under complete control). // a: .. STOW s die „„ -.., 3__k--_-7-..„ -__:+r-r_. • , lil- - ' „.....441111L",v 14\ f ---4 ' 411"-- t e` ` y 4 ., ---, - ---- -_, u t 4 `' �.Ya 1 ti.....- y ,i � 1111.111. .. 4 � l w: _ i , . qtc‘ Water was then bullheaded into formation to cool the geothermal reservoir, (1" valve and %" valve closed while forcing cold water into the formation) at least 300 gallons were forced into the formation, which was then later followed with 28 cubic feet (equivalent) of TC Geolite TM cement. TWA �. y . A..'J �C. ."� '` _ _"-"�'... ,�� �r .:....•: 411- Tom^ L r ..!, w lillka 04001:00, 7111104. ' .'..-.:_- /V ' ' - ..-7% . f / ' 410, / s..,,, N • - , t ‘',. • After cement was successfully pumped in through the tubing and returns were seen at surface, an annular squeeze was then performed as cement was pumped directly into the annulus as well. Afterwards, the well was shut in (all three valves: 1.5", 1" and the %") over night to let the cement settle. .r n ' •[ r� gni '( to „ , . . ..,,._ -... r i' I, sn 1 .i7t .br The next morning (9-Sept-2013) the valves were re-opened, no pressure was observed at all, and they were all removed to perform a "top job" which was to refill any cement in either the tubing or annulus that had fallen back. All three openings to the flange were full with 13.5 ppg cement slurry and well is safely full of cement in all orifices. 1. • . . 4141tif; - cf-i1/41 "''''''' ., . 1. • '' ..v;± tr,.. X'1 7it Y z.,...x......44„../ _. ____ . .. ...,___ .10-1. r "�a:. - ydyr.. /` dir '4�. A. 4� , N v - - 1_. }�I� 00, .... ,,,, , „ Finally, bull plugs were fastened over the 1.66" tubing, and the 1" and %z" openings (all filled with cement). Currently fastened in, but scheduled to be welded on as the final step of abandonment. • OF 7W w��\\I%%s THE STATE Alaska Oil and Gas �`� ALASKA� 'onservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue OFALASY'� Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Herman J. Scanlan City Administrator City of Akutan -7 3380 C Street, Suite 205 l 0 - 0 '// f Anchorage, AK 99503 Re: Hot Springs Bay Valley, Hot Springs Well-2 Sundry Number: 313-428 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. , oerster Chair DATED this Z day of August, 2013. Encl. • RECEIVED STATE OF ALASKA AUG 0 7 20', ALASKA OIL AND GAS CONSERVATION COMMISSION g(/2 /J 3 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon' Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program 0 Suspenn Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown Re-enter Susp.Wet ❑ Stimulate❑ Alter Casing❑ Other: 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: City of Akutan Exploratory 0' Development ❑ 210-071 • 3.Address:3380 C Street,Suite 205,Anchorage,AK,99503Stratigraphic ❑ Service ❑ 6.API Number: 50-295-20002-00 ' 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? %"2-" 1-kii- ,1pJ5 kW( -2_ 0113 Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): Fee• 10.Field/Pool(s): Hot Springs Bay Valley 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 833 • 833 <833 . 833 Casing Length Size MD TVD Burst Collapse Structural Conductor 37 6.625 37 37 1620 1370 Surface 157 4.5 157 157 3135 2299 Intermediate 604 3.5 604 604 9850 8770 Production Liner 4 818 1.66 818 181 3690 4440 Perforation Dept i D(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 12.Attachments: Description Summary of Proposal ❑✓ . 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch I. 1 Exploratory 1✓1 • Stratigraphic 1 1 Development r i Service ❑ 14.Estimated Date for Sept.6,2013 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned E. Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Email a 1,,,-ilL., dw1..,D9 c i.....-/- Printed Name -L--ko9u Z-, S ' I Title /� VY A4 WI�I —C Signature Phone l l Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 313- uag Plug Integrity 0 / BOP Test 0 /Mechanical Integrity Test 0 Location Clearance Other: pj O44 oL J' Q-- 7riO soc,r-+ - £ (....., e49' Pl4 Spacing Exception Required? Yes 0 No12/ Subsequent Form Required: /3--zf 07 APPROVED BY Approved by: �/i COMMISSIONER THE COMMISSION Date: `)—/Z._/3 RBD S SEP - 9 20- \. t. Y•i3 ,,!� Form 10-403(Revised 10/2012) A rov^ n Submit Form and �w �� pp �d�pRa c�1•i�i Anbhs f m the date of approval. Attachmennn in D plicate ..6 hm 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 Attachments: Akutan Well 2 and 4 Abandonments.docx a!D —071 Guy, Zoo a73 . 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. --- /Ca 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. afr If you are available next week, I would like to give you a call. Alan Bailey Manager of Engineering Geothermal Resource Group, Inc. alanbailey(ageothermalresourcegroup.com 760-341-0186 Office 760-341-9673 Fax 775-304-3253 Cell www.geothermalresourcegroup.com iici',nt', Akutan TG-2 "Hot Springs"Well I III I 6-5/8" Conductor at 3/' Fully Cemented 2i0- 0 7 0 4-'6" 0.25 WI Casing at 157' f Fully Cemented 4 o1 B 15( S 35* 3-W' 0.25WT Casing at 603' a -3 n Loss Zone at 746 8/71 3.011 Open Hole to 833" _ 1.660" 2.4ppf I ubing, Hung from Surface to 818' -4 -0 ADDENDUM Akutan Geothermal Resource Assessment July 22, 2011 By � Amanda Kolker,AK Geothermal 1 '"k\-(/ " Alan Bailey, Geothermal Resource Group 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 wellfield 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 33.5°/ 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). i +. l fi•-•`- .— ad lrlit4 rr f,r / -,..--/ ,J, .. �4Mill 111.1 ...., .11W r y j 41 -• \ ---%'''*- \ \ k,' I i (.7 , -------„„ „, ) .iI??w I --_- N. ti,po(1 �s A If rn _ N'1.) \ V<,'!-,s, o .N....,,, .....___, ..- \ ' --, ." 44.41 4. , i )) \`'N t_ -Nal a U.4 i __.----• ) </ 0,....\\N t`-- —._....,n„..\--,.., `�'�— .k ----, __ ..\\ \\,.. \X 01 : ' -.7) \ .dry �.�.---� l \ 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). --.„-: :_,.._ ....., , . A., , • �..- . .,....., , r-- -...,,. .... „,...,.........„....„-, .,,,,,,,,,,--,...„4-,,, ,,,) , , „, . IM s ' i; ' /, 1,..,,, „iii �-- „ ............_ .., ..__ I�i c't`r e 0 3� i~• �ll ► r��rd �'4r^ W, 2 ,ai �____.s- 14 • FA ', -'---_ 5 ti Nq 5Vr 44�S' ci: :: #ILAtSl R. \ sAk �Yy L Gr'.. NM�, 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 W53 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. li t t "• r 1L a,,,....,,._� 4 i{ . i. 4, __ m T ` w- � ih Idol'ikt — ,+ b!i.l -.wr.� 'per "-f X ,,,rte �•�1 o O c `o,o c. Ilk ■ E� ,, ,.'/ .� X, . "-- Ails... .. �,"` r O4,44 All. 4 o" s; ....,,, , rd . i"� _ �.__,. ..._ A _._. :* .lam .� ': • �r CV i i Z N`J ;j j 6• " , )),,,, N,. \ , sio:ro:". 0, ::. :A?°,° ,. te '°N. C , i ' , .. ,le ,-` , '1 /8 I ,` ., .r � s nf'n utivti It 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 — r. 50 r' r JF B ,So.,G • ,I 6001 ill ] "C NNN.f.ci i� • 1 ..c il •.fr\.S. ,•.) ''' ''''''' - • ,* . • • .. 6000 — : ' F-A \' ( \ . t6;.:.r'.,'4.,,.,.\ ''. V1-C,B,A . . TG» 5999 `` .1 ;. 7 50 0 •,..N. ,. - • • ,. '. . :2 c . . • 5998 =_e:eR 440 441 142 443 444 0 1 2 `Mapped Isotherm Akutan Geothermal Project fault 50°C interval Km WastamG.ao 30 MT 21 Sep-2009-Cumming Gao.ei.nc. Thermal Gradient .., Inferred Isotherm Resistivity Cross-section CM2(UTM km WGS84) well . fault 25°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 ao - off' Akutan Geothermal Resource Assessment Commissioned by City of Akutan, Alaska As part of its Geothermal Development Project June 2011 Ilit 1a 3 .. ti , '.d' `R iS -?, i, '',44,f „„ ' - , `'`I'4-, ".1.-1,:•44':if- ' :,,,,fir , --- --)tdr 6 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 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, Mmax = 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. 166'4'0'W 166'0'0"W 165.56'0"W 1x5.520 W 165.48'0"W qr g 54.1271,1 i !t - '�, n • 1 0.5 0 1 2 3 kiomeler4.;. - F: ;%, -4,.::,„..... .;?;.3.,.1,--:-.--, . _ ', 1 o.5 0 1 2 3 Miles 1,31„:;,,v ..„ ..-,1. : ..__ . ,...1_ , . „,, , , ,„ , ... 1 i , ...,.,,, 1 N , ty.. C . '` r( r t�, L . -t .Inr ,�. ..,. 'f.+,y .f 54•Wr 4 -'''''- :•.;tI7 b .:"544",:.I''''''. e. - • ,e( .1 '0” 4e �.�jCutan village a ca N s or.,,,,ik ,,... r Legend ,t $y 1, •j `� , x` - fir! 5e4�0 Geothermal project area i, . ,, ,t •1 =: .4' • Hot springs t 4,- ) 4w t- � :4 `l.rat , % 11111 Fumarole area Fault lines : jr • ,._'C+ 4fi I I Rift zones n t^ v _i>.."':."":".!;;1... . ' ,.:,,,rte. '' 166.0'0"W 165.56101W 165'52'0"W 165'487W 165.447W 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 + ,,....„. • _, # ) ... ..0.git , ,,,1 . 0 i . 1. fz, boo, ir. 4 ./ ,, . _. . t''' i I (--'"T 4 ,Aiiik.._ .)., '',1 '="dilgt`k) it,:Hs':s3 / - .0.h ,1• lr .024..,... rl /� f: � , `s ,. .� . � �" - ;367 / ' # c §. 1 S ( i..w. f,h'1 lw 1 h ." ,. '...tel 4 •it ,, • ,, , . \,,,,,, ',c,.,1-:, I: 'N',\::*---" ' , or., , ..,,tC \ li -:::—` ::''''.11:"::::•. \-\\---1‘. ' IP\ ' ,lransmis son 7r nes .,. - { �� r �+rA I oh),r \ „„. ----„, _ A ...,,„,......„. .4. . ____ ,.., , f." is„:„..,,S-A'i• 'inn:. 1 --IV- ,j % t,*, \ �J?// - Miles. k--., Fumaroles 0.25 0.5 1 1.5 2 -- --` Well Location ' Mete- _ ,w��_\----\_,..__- a illi' 0 250,‘ ,00 5 1 Ooo 1.500 2,000 oi,,,, ` -- • Hot spring + , - -r,1K 11 ••-Transmission Lines(approxi1.\ �rI •—• Akutan project area , .}' \ -r I-: , _ 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 -1 0 - - -200 -400 k -- - N W -600 ° -800 - QJ "' -1000 TG2 -1200 —Boiling 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 - 100 200 —— — 300 40044. 500 0 C v 600 W a , 700 -12h 08-2010 — -24h 08-2011 800 —36h 08-2011 -May-11 900 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 - 200 - -- \ 400 CE 600 a▪, cu 800 1000 v 1200 12h 08-2011 24h 08-2011 1400 _-- 36h 08-2011 — May-11 1600 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 — — ita200 ` it 400 -- J • 600 C▪U CV 800 c▪o a, 1000 - W 1200 --- TG2-05 2011 TG4-05-2011 1400 —Boiling 0.1%NCG 1600 r i 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-T1,°F) 0 • • • — — • • •• • S.•• ' ■ 200 •• • a ■ • ♦ • a a ■ 400 •�■ ■ a Ira as 600 as J N • < 800 ■ • cu •,f = 1000 • o •• • c4'a • •i ■TG 2 > 1200 •• d 1 3 •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-CI 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.Geothermomet y 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 microlites, 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 0 E #; __ 0 0 °t Heu t Smectite 1:c co4. 1s Illit 100 N\'• Smectite ��` -- 1Sc Yug '+ 50 itl 16°Chab , kA 115 1'Ep P00 E- -4 300 100 —`—. — _._ __._ . E- 1``Lau 4 1"Adu IS E Smectite 11St Wai -.0 I _- .+._ 400 a 2 Adu:Adularia Chab:Chabazite $ 150 - --- --- - Cptl:Clinoptilolite11 500 Ep:Epidote • Heu:Heulandite g Smectite Lau:Laumontite /. P Pre:Prehnite ilio • 2 Y2"casing shoe i Wai:Wairakite ` Yug:Yugawarilite 600 200 I -0-Temp 12 hours heating tIlit -A-Temp 24 hours heating -f-Temp 36 hours heating 11110 4 700 Smectite ' p Temp 48 hours heating 11$ II, 0 Temp 271 Days heating 250 ___.__— -f-BPD Temp 800 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 Well Temperature(°C) 0 50 100 150 200 Meters Feet 00 1'rChab 50 Smecttte — 1st Adu E 1st Yug ♦� 200 Smectite i 1 st Lau 100 . 1"Mord E \ O - * 0 -4-'4'-1"Ep 0 /1"Mite ` O 400 ' 1"Heu ► • 150 '- 15tAnal "t Smectite Smectite , � 1 600 ► 2 A"casing shoe `, 200 0 E t• O o Smectite 'c• .... 800 250 - .. _ 1 .•..a 4 1" • It,• • . • F• - • V 300 — ,,• __— I 1000 • 350 -- _- _ - • List Pr Adu:Adularia 'Q 'E 1200 Anal:Analcime Chab:Chabazite Cptl:Clinoptilolite -+-Temp heating 12 hrs 400 Ep:Epidote -,t--Temp heating 24 hrs Heu:Heulandite O —if p(stron ) -IF-Temp heating 36 hrs 0 E_+ Lau:Laumontite 0 Mord:Mordenite 0 Temp heating 260 days O '- 1400 Pre:Prehnite - -BPDTemp O O Yug:Yugawarilite O 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 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. 6w2- 1/1 '�., ..e'k'.-"' A005 11010.. • i •'�,, AO°c '! J3,Ohm.m r`��.. \ • Of • _. 200 .. •♦ i, 150 6001 --,"' ♦ 4„, 120 100 G • _ 70 I .f poi 30 ,�O 20 1 15 CC, • . • 1 boon _ -.1. 1 • G�� • i. til �Up ,.( i • Mui 5 f, S "C TG4 ii- c ne= t, g 5998 -• if-. ilillibir 440 not ,!. 444 44t 446 0 1 2 `Mapped Isotherm Akutan Geothermal Project Km fault 50 C interval WesternGeco 3D MT 22-Sep-2009 -Cumming Geoscience Thermal Gradient •♦ Inferred Isotherm well ♦♦ fault 25°Cinterval Resistivity Cross-section CM1(UTMkm WGS84) 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 800 800 " Fumarole o TG4 400 � < TG2 200 r �' �,�, < <W .T°1RZS 3 - 0 i Sod t e • • 1SP'C I t 200- — L—' au 400- 4 - � .. 5 C I . I V1 800 r ,,,,,c �00'C. 5erc ( -800- 1 s.,s. / � E woo /' \` c 1200-�, ' 1 \ 63-1400- / �� �• ♦`vac. W-1600- / \ 1 \ -1800 / \ ,`` ..:;� ., ..• \ �.` 1 -2000 ,.h 1 1 •2200 • —..... -2400 -2600 `♦ -S.` -2800 S. `...4.4.t„. rc, s. 5_� -3000 _ --- • 0 1 2 3 4 5 6 Distance(Km) Resistivity iOhm mf120 s0 20 10 00 k 40 Er' 15 I 7 l herm I flowwater Gradient aWelt 50°Ctme interval I 120 50 L 1 0 20 10 5 depth slice 4�Fault(dashed Isotherm Akutan Geothermal Project - for map • where inferred) 25°C interval West•mG•oo 3D MT 22S•p•2008 •Cumming Geoseuno• Resistivity Cross-section CM1 (uTM km WGse4) 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 ; i 6002 — Fr 5 • i r`f Ohm r 6001 _.�, 175 F ,-,C,,-,C, �� ,�' Ns< & • *NN _ •,,,e' , •. 6000 f JJ 64...s.k...ivzi.,, 5999 , ,,.•«,.. }Yqµ. (5 i . }u • .. 3 5998 />; 440 441 442 443 444 445 446 0 1 2 Ni.Mapped Isotherm fault 50°C interval ____,,._Aktrtan Geothermal Proj�Ct_ --- Km WestemOew 3D MT 22.S.p-2008-Cumming Ows°ienw Thermal Gradient ....S.. Inferred Isotherm welldi '• fault 25°C interval Resistivity Cross-section CM2(UTM km WGS84} Figure 12.Map view of"Conceptual model 2,"showing outflow beneath the mountain to the north of H58V. 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 800 600 400 - '..4111111111111 200 e' -200 ,`yd -400 / � ', -600 �,so rri . ...'..(..........„.. tO -800 I 1000 1, i `.�` f C. // I 0-1200 11y e X �1 ,„ tti-1400 ‘ 1: ,..............,...,,,,. ...„. ... ..._.% i �' rL� W-1600 /` \\1/4:\ �` 1 i` _ ,Pile'-1800 // �1 �� _ `.."_">�,2000 �. X j2 .w.-2200 iN. ` •'*C ^a-2400 \ �"7-2600 � `-2800 3�` ~°+ ` `� -3000 ~ ~ w. 0 1 2 4 5 Distance(Km) 3 Ohm m 120 i 5020 10 I 200 t40 15 7 I owater Gradient lWell Isotherm 5O°C Interval130 12 1 50 17 20 �10 5 depth slice J Fault(dashed Isotherm Akutan Geothermal Project - for map f where inferred) 25°C Interval WestemGeeo 3D MT 224Sep4009•Cumming Oeosoienoe Resistivity Cross-section CM2(UTM km WG884) 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. Its,e)T I �� r \� ( N � , SA Ridat •• Rid . j , �( \ \‘' 4 -ii''..—.. 19:t /0009'-: �,.11CCI % r y �c 43z7 ss�r�jj� i .r I L o�c • = ,;. � LL'‘ �2,, i ' T / (1 ',-.:'-'7 (cj‘i ( jkt: .r. ,..1 . cx � h �, __ ._ �� IS ` _p A - _ _ _ _ . it— W \tel I'.. i_, f �M �, - 5 -`titin r .,... ___:___ rc,.1...,..: ,, 1 ,z., -lgiolob* As ,,,i s r‘. r 1 ''e / t �,,.;, 11 � , Akutan Figure 14. Map showing possi.le wellpad 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 p Y 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-full.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 Winton Aubert/Steve Davies RECEYFD Alaska Oil &Gas Conservation Commission 333 W. 7th Ave.,Ste. 100 SEP 1 0 2010 Anchorage,Alaska 99501 n y,!,ni. i Amanda Kolker on behalf of The City of Akutan 5258 NE Cleveland Ave. Portland, OR 97211 September 8, 2010 Dear Mr. Aubert and Mr. Davies, Enclosed please find the hard copies of the end-of-well reports for the two wells drilled for the Akutan Geothermal project. Also enclosed are the well logs and pressure-temperature (PT) logs for each well. Electronic copies of all these files were sent as a zipped folder to your email addresses September 7, 2010 Please let me know if you have any questions, or if I am missing anything. Thank you, Amanda Kolker Akutan Geothermal Project Manager infoak-geothermal.com 971-322-5002 ki CA- STATE OF ALASKA oil VS (20 !a ALASKA vlL AND GAS CONSERVATION COMMISS,A WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑✓ Abandoned ❑ Suspended lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑] 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.: 8/8/2010 • 210071 - 3.Address: 6.Date Spudded: 13.API Number: 3380 C Street,Suite 205,Anchorage,AK 99503-3952 7/16/2010 • 50-295-20002-00-00 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 2325'E,500'S,S32,T69S,R112W.SM . 8/5/2010 • Hot Springs Well/2 . Top of Productive Horizon: 8.KB(ft above MSL): 83.5 15.Field/Pool(s): 2325'E,500'S,S32,T69S,R112W.SM GL(ft above MSL): 77 Hot Springs Bay Valley,, / .. Total Depth: 9.Plug Back Depth(MD+TVD): '4 t__-/ (ZE�)�d'`'A 2325'E,500'S,S32,T69S,R112W.SM N/A G�zo ..t..t.,&ez 9.i'(/i 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x- 531250 • y- 56490 • Zone- 8 •833'+833' . Fee Agent Corporation TPI: x- 531250 y- 56490 Zone- 8 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 531250 y- 56490 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 MC 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 ,,UN FT LJL GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD .PLE� 6.625 20 K55 0 33 0 33 9.875 Tremie w/13.5#Type 2 Premiu.8"j.S a 1s 4.5 11.2 4130 3 157 3 157 5.5 13.5#Type 2 Premium w/30% 83.1 a old* 3.5 8.69 4130 3 603 3 603 ,3.87 13.5#Type 2 Premium w/30% $'(•T ti 1, 24.Open to production or injection? Yes El No❑ If Yes,list each 25. TUBING RECORD interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Foot valve at end of 1.66"tubing-tubing can only be circulated from surface. 1.66 818 0(hung from wellhead) 031P� 26.11 ACID,FRACTURE,CEMENT SQUEEZE,ETC. DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 603-623 1 bbl of 13.5#Type 2 premium cement w/30% ae -' %4 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 ❑✓ 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. RFC !\/ECS RBDMS SEP 0 9 2010 ()E-F 1 0 2010 Psl' C .Com i ffi (: 8 i.4r :1 �e:r� CUP, ae�i+lltdSS1031 Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit original only ...... ..._ 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑✓ 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 173'. Performed test to Alluvium 5'to 52' 5'to 52' full leakoff at 623', leakoff obtained at 0.52 gradient. Squeezed cement and Akutan 52' 52' tested again, leakoff obtained at 0.74 gradient. Well allowed to flow after completion of drilling and formation fluid samples were obtained. (mixed volcanics/volcaniclastics) Formation at total depth: 833' 833' Akutan volcanics (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 -----4Signature: L---------- 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 Logging Worksheet-Hot Springs Wen 4. Last Circulation Time: rLast Circulation Date. i�) 1 Survey 1 Survey 2 Survey 3 Start Time: Start Date °- -7_5 StartTime: Start Date. Start Time: Start Date: Depth Time .). 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LO:S OIOZ/8/8 Htia 1%-1 6b:b OIOZ/8/8 X =_ I£:b OIOZ/8/8 Q LIII 2 'a £I:b OIOZ/8/8 SS:E OIOZ/8/8 L£:£OIOZ/8/8 61:E O10Z/8/8 I0:£OIOZ/8/8 £b:Z OIOZ/8/8 SZ:Z OIOZ/8/8 LO:Z 0t0Z/8/8 6b:1 OtOZ/8/8 t£:t OtOZ/8/8 £I:t OtOZ/8/8 SS:O 0toZ/8/8 — — - - L£:0 ot0Z/8/8 vii O p o O N rl r 1 Temp Logger Time Fahrenheit(°F) Serial Number 1 8/8/2010 0:37 141 10002137 2 8/8/2010 0:38 142 3 8/8/2010 0:38 144 4 8/8/2010 0:39 144 5 8/8/2010 0:39 146 6 8/8/2010 0:40 147 7 8/8/2010 0:40 148 8 8/8/2010 0:41 150 9 8/8/2010 0:41 151 10 8/8/2010 0:42 153 11 8/8/2010 0:42 154 12 8/8/2010 0:43 156 13 8/8/2010 0:43 157 14 8/8/2010 0:44 159 15 8/8/2010 0:44 160 16 8/8/2010 0:45 162 17 8/8/2010 0:45 164 18 8/8/2010 0:46 166 19 8/8/2010 0:46 169 20 8/8/2010 0:47 171 21 8/8/2010 0:47 177 22 8/8/2010 0:48 181 23 8/8/2010 0:48 182 24 8/8/2010 0:49 184 25 8/8/2010 0:49 191 26 8/8/2010 0:50 193 27 8/8/2010 0:50 192 28 8/8/2010 0:51 198 29 8/8/2010 0:51 207 30 8/8/2010 0:52 212 31 8/8/2010 0:52 212 32 8/8/2010 0:53 213 33 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IIMENNNI • J\44.4.h..t4 ► P4•4\' .'I'-4 •+.+.',P"1' 0> 0 •4•4•41/44401\-4,41.4,4\rl'.h•\+.4‘4. 4.44N't\J\ —0 —0 4.4-4-4,-1,44-4-44-4-4,4-4-4,4.4-4,44,4,44 `-U `0 10 810 820 830 840 850 860 870 8€ G ~ am a o oa ue, oa o0 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well Field: Hot Springs Bay Va Sect: 32 Town:69S Rng: 112W County:Aleutians East State:AK Report No: 1Report For 10-Jul-10 Operator: City of Akutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 0 Drilling Days: 1 actual/22 plan RKB Elevation: 4.00 County: Aleutians East Vertical Depth(ft): 0 Days On Location: 1 Last Casing: Field: Hot Springs Bay Hole Made: 0 Spud Date: 16-Jul-10 Next Casing: 6.625 at 30 Working Interest: Drilling Hrs: 0 Average ROP: 0 Last BOP Test: Personnel: Operator: 3 Contractor: 3 Service: 6 Other: 2 Total: 14 Current Operations: Operations idle for night. Planned Operations: Continue to mobilize rig and equipment. Toolpusher: David Griggs. Welisite Supervisors: Alan Bailey, Randy Baldwin Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 7:30 17:30 10.00 0 MOB Sling loads to drill site. Dug cellar and began constructing sump. Comments Well site under construction. Began moving equipment to well site. Cost/AFE Information AFE No AFE Description AFE Amount Daily Mud Well Mud Daily Total Well Total %Spent No AFE Assigned 0 0 0 210,860 210,860 Totals$: 0 0 0 210,860 210,860 Rig Information Equipment Problems: Location Condition: Transport: Safety Information Meetings/Drills Time Description Safety 15 Pre-job safety meeting with all personnel, First Aid: Medical: Lost Time Accidents: Days Since LTA: 0 ❑ BOP Test ❑ Crownamatic Check Printed: 19:50 13-Sep-10 RIMBase 5.1.1.177 Page: 1 of 1 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well Field: Hot Springs Bay Va Sect 32 Town: 69S Rng: 112W County:Aleutians East State:AK Report No: 2 Report For 11-Jul-10 Operator: City of Akutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 0 Drilling Days: 2 actual/22 plan RKB Elevation: 4.00 County: Aleutians East Vertical Depth(ft): 0 Days On Location: 2 Last Casing: Field: Hot Springs Bay Hole Made: 0 Spud Date: 16-Jul-10 Next Casing: 6.625 at 30 Working Interest: Drilling Hrs: 0 Average ROP: 0 Last BOP Test: Personnel: Operator: 3 Contractor: 3 Service: 6 Other: 3 Total: 15 Current Operations: Rig idle for night. Planned Operations: Continue to mobilize rig and equipment. Toolpusher: David Griggs. Wellsite Supervisors: Alan Bailey,Randy Baldwin Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 7:30 20:00 12.50 0 MOB Sling loads to camp and well site.Constructed sump at rig site.Set and leveled rig base. Comments Unloaded containers,continued to move loads to drill site and camp.Continued well site construction.Set-in and leveled rig base. Cost/AFE Information AFE No AFE Description AFE Amount Daily Mud Well Mud Daily Total Well Total %Spent No AFE Assigned 0 0 0 3,210 214,070 Totals$: 0 0 0 3,210 214,070 Rig Information Equipment Problems: Location Condition: Transport: Safety Information Meetings/Drills Time Description Safety 15 Pre-job safety meeting with all personnel, First Aid: Medical: Lost Time Accidents: Days Since LTA: 1 BOP Test ❑ Crownamatic Check Printed: 19:50 13-Sep-10 RIMBase 5.1.1.177 Page: 1 of 1 Daily Drilling Report Geothermal Resource Group q.0 Well ID: AGP TG-2 Well Name: Hot Springs Well Field: Hot Springs Bay V2 Sect: 32 Town:69S Rng: 112W County:Aleutians East State:AK Report No: 3 Report For 12-Jul-10 Operator: City of Akutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 0 Drilling Days: 3 actual/22 plan RKB Elevation: 4.00 County: Aleutians East Vertical Depth(ft): 0 Days On Location: 3 Last Casing: Field: Hot Springs Bay Hole Made: 0 Spud Date: 16-Jul-10 Next Casing: 6.625 at 30 Working Interest: Drilling Hrs: 0 Average ROP: 0 Last BOP Test: Personnel: Operator: 3 Contractor: 3 Service: 6 Other: 4 Total: 16 Current Operations: Rig idle for night. Planned Operations: Continue slinging loads to camp and rig site.Continue digging sump.Rig up camp. Toolpusher: David Griggs. Wellsite Supervisors: Alan Bailey,Randy Baldwin Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 7:30 19:30 12.00 0 MOB Moved loads to camp and rig site.Set up VHF repeater.Continued digging sump at rig site. Comments Moved equipment to well site and camp. Set up VHF communications. Continued sump construction. Cost/AFE Information AFE No AFE Description AFE Amount Daily Mud Well Mud Daily Total Well Total %Spent No AFE Assigned 0 0 0 3,210 217,280 Totals$: 0 0 0 3,210 217,280 Rig Information Equipment Problems: Location Condition: Transport: Safety Information Meetings/Drills Time Description Safety 15 Pre-job safety meeting with all personnel, First Aid: Medical: Lost Time Accidents: Days Since LTA: 2 BOP Test Crownamatic Check Printed: 19:50 13-Sep-10 RIMBase 5.1.1.177 Page:1 of 1 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well Field: Hot Springs Bay Ve Sect: 32 Town:69S Rng; 112W County:Aleutians East State:AK Report No: 4 Report For 13-Jul-10 Operator: City of Akutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 0 Drilling Days: 4 actual/22 plan RKB Elevation: 4.00 County: Aleutians East Vertical Depth(ft): 0 Days On Location: 4 Last Casing: Field: Hot Springs Bay Hole Made: 0 Spud Date: 16-Jul-10 Next Casing: 6.625 at 30 Working Interest: Drilling Hrs: 0 Average ROP: 0 Last BOP Test: Personnel: Operator: 3 Contractor: 4 Service: 7 Other: 3 Total: 17 Current Operations: Rig idle for night. Planned Operations: Continue to sling loads to drill site. Finish rigging up rig and setting up camp site.Complete sump. Toolpusher: David Griggs. Wellsite Supervisors: Alan Bailey,Randy Baldwin Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 7:30 20:00 12.50 0 MOB Continued moving material to camp and to well site. Continued digging sump.Began rigging up. Comments Continued moving equipment to well site and camp and began 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 3,210 220,490 Totals$: 0 0 0 3,210 220,490 Rig Information Equipment Problems: Location Condition: Transport: Safety Information Meetings/Drills Time Description Safety 15 Pre-job safety meeting with all personnel, First Aid: Medical: Lost Time Accidents: Days Since LTA: 3 0 BOP Test ❑ Crownamatic Check Printed: 19:50 13-Sep-10 RIMBase 5.1.1.177 Page: 1 of 1 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well Field: Hot Springs Bay Ve Sect: 32 Town: 69S Rng: 112W County:Aleutians East State:AK Report No: 5 Report For 14-Jul-10 Operator: City of Akutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 0 Drilling Days: 5 actual/22 plan RKB Elevation: 4.00 County: Aleutians East Vertical Depth(ft): 0 Days On Location: 5 Last Casing: Field: Hot Springs Bay Hole Made: 0 Spud Date: 16-Jul-10 Next Casing: 6.625 at 30 Working Interest: Drilling Hrs: 0 Average ROP: 0 Last BOP Test: Personnel: Operator: 3 Contractor: 7 Service: 7 Other: 5 Total: 22 Current Operations: Rig idle for night. Planned Operations: Sling loads.Pre-check rig,raise derrick.Rig up pumps and mud pits. Toolpusher: David Griggs. Wellsite Supervisors: Alan Bailey, Randy Baldwin Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 7:30 19:30 12.00 0 MOB Unable to sling loads due to fog.Continue rigging up camp.Continue rigging up rig. Finish digging sump. Install sump liner. Comments Weather delay due to foggy conditions-helicopter could not sling loads.Continued to rig up and set up camp. Sump was completed and liner set. Cost/AFE Information AFE No AFE Description AFE Amount Daily Mud Well Mud Daily Total Well Total %Spent No AFE Assigned 0 0 0 3,205 223,695 Totals$: 0 0 0 3,205 223,695 Rig Information Equipment Problems: Location Condition: Transport: Safety Information Meetings/Drills Time Description Safety 15 Pre-job safety meeting with all personnel, First Aid: Medical: Lost Time Accidents: Days Since LTA: 4 ❑ BOP Test Crownamatic Check Printed: 19:50 13-Sep-10 RiMBase 5.1.1.177 Page: 1 of 1 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well Field: Hot Springs Bay Va Sect: 32 Town:69S Rng: 112W County:Aleutians East State:AK Report No: 6 Report For 15-Jul-10 Operator: City of Akutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 0 Drilling Days: 6 actual/22 plan RKB Elevation: 4.00 County: Aleutians East Vertical Depth(ft): 0 Days On Location: 6 Last Casing: Field: Hot Springs Bay Hole Made: 0 Spud Date: 16-Jul-10 Next Casing: 6.625 at 30 Working Interest: Drilling Hrs: 0 Average ROP: 0 Last BOP Test: Personnel: Operator: 3 Contractor: 7 Service: 7 Other: 5 Total: 22 Current Operations: Rig idle for night. Planned Operations: Finish rigging up. Hold safety meeting and drill ahead. Toolpusher: David Griggs. Wellsite Supervisors: Alan Bailey,Randy Baldwin Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 7:30 21:00 13.50 0 MOB Continued rigging up rig.Raised mast. Installed new wire line.Added mixing water to sump and pits.Began building bridges over creeks going to camp. Comments Continued rigging up.Raised the mast and installed new wire line.Added mixing water to sump and pits.Bridged creeks going to camp. Cost/AFE Information AFE No AFE Description AFE Amount Daily Mud Well Mud Daily Total Well Total %Spent No AFE Assigned 0 0 0 17,810 241,505 Totals$: 0 0 0 17,810 241,505 Rig Information Equipment Problems: Location Condition: Transport: Safety Information Meetings/Drills Time Description Safety 15 Pre-job safety meeting with all personnel, First Aid: Medical: Lost Time Accidents: Days Since LTA: 5 ❑ BOP Test Crownamatic Check Printed: 19:50 13-Sep-10 RIMBase 5.1.1.177 Page: 1 of 1 Daily Drilling Report Geothermal Resource Group q40 Well ID: AGP TG-2 Well Name: Hot Springs Well Field: Hot Springs Bay V8 Sect 32 Town: 69S Rng: 112W County:Aleutians East State:AK Report No: 7 Report For 16-Jul-10 Operator: City of Akutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 37 Drilling Days: 7 actual/22 plan RKB Elevation: 4.00 County: Aleutians East Vertical Depth(ft): 37 Days On Location: 7 Last Casing: Field: Hot Springs Bay Hole Made: 37 Spud Date: 16-Jul-10 Next Casing: 6.625 at 30 Working Interest: Drilling Hrs: 3.5 Average ROP: 10.6 Last BOP Test: Personnel: Operator: 3 Contractor: 7 Service: 7 Other: 4 Total: 21 Current Operations: Opened hole to 7-1/2 inches f/25't/37'with full returns. Temp out=52 degrees. Planned Operations: Open hole to 9 7/8 inch.Run and cement 6 5/8 inch conductor, Toolpusher: David Griggs. Wellsite Supervisors: Alan Bailey, Randy Baldwin Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 7:30 14:00 6.50 0 MOB Finished rigging up. 14:00 15:00 1.00 0 MIXMUD Mixed spud mud. 15:00 15:30 0.50 0 SAFE Held pre-spud safety meeting. 15:30 19:00 3.50 37 DRIL Cored 5 1/2 inch hole surface to 37'with full returns.No fill. 19:00 19:30 0.50 37 TRPO POH. Hole flowed approx 5 gals/min.of 120 degree water. 19:30 0:00 4.50 37 OPEN MU 7-1/2"milltooth bit.Opened hole surface to 25'. Management Summary 9-7/8"bit in Dutch Harbor-unable to mobilize it due to weather. Comments Rig idle for night.Finished rigging up.Held safety meeting with all crew members.Mixed spud mud.Cored 5-1/2"hole surface to 37'.Opened hole to 7-1/2"t/25'. CostJAFE Information AFE No AFE Description AFE Amount Daily Mud Well Mud Daily Total Well Total %Spent No AFE Assigned 0 0 0 42,194 283,699 Totals$: 0 0 0 42,194 283,699 Mud Information % Gels Temp Density Vis PV YP Filt. Cake pH Solids Oil Water Sand Chloride Calcium 10s 10m 30m In Out 16-Jul-10 12:00 at Depth 0 ft Sample from Mud Pits,Type:Low Solids Non-Dispersed 8.50 45 52 52 Mud Consumables Item Description Qty. Cost Item Description Qty. Cost Gel-100#SK 42 0 Soda Ash-50#SK 3 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 1 1 ADT 2AO 5.500 0 37 4 9.2 9 Jets: Out: 37 Grade: Cutter: 2/2 Dull: WT/ Wear:A Brgs: Gge: 0 Pull: TD 2 1 B HUGE GT-1 7.500 0 25 4.5 5.6 80 9 200 Jets: 18 18 18 Out: 37 Grade: Cutter: 2/2 Dull: WT/NO Wear:A Brgs: E Gge: 0 Pull: TD Rig Information Equipment Problems: Location Condition: Transport: Safety Information Meetings/Drills Time Description Safety 15 Pre-job with both crews. First Aid: Medical: Lost Time Accidents: Days Since LTA: 6 ❑ BOP Test ❑ Crownamatic Check Printed: 19:50 13-Sep-10 RIMBase 5.1.1.177 Page: 1 of 1 /,. Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well Field:Hot Springs Bay V8 Sect: 32 Town:69S Rng: 112W County:Aleutians East State:AK Report No: 8 Report For 17-Jul-10 Operator: City of Akutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 37 Drilling Days: 8 actual/22 plan RKB Elevation: 4.00 County: Aleutians East Vertical Depth(ft): 37 Days On Location: 8 Last Casing: Field: Hot Springs Bay Hole Made: 0 Spud Date: 16-Jul-10 Next Casing: 6.625 at 30 Working Interest: Drilling Hrs: 0 Average ROP: 0 Last BOP Test: Personnel: Operator: 3 Contractor: 7 Service: 7 Other: 4 Total: 21 Current Operations: Waiting on equipment due to weather. Planned Operations: Open hole to 9-7/8".Run and cement 6-5/8"conductor Toolpusher: David Griggs. Wellsite Supervisors: Alan Bailey, Randy Baldwin Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 3:00 3.00 37 OPEN Opened hole to 7-1/2"f/25't/37'with full returns.Temp out=52 deg F. 3:00 4:30 1.50 37 CIRC Circulate and clean hole. 4:30 5:00 0.50 37 TRPO POH. 5:00 0:00 19.00 37 WOE Continued to sling loads w/helicopter while wating on 9-7/8"bit. Set up living quarters X on well site. Management Summary 9-7/8"bit in Dutch Harbor-unable to mobilize it due to weather. Comments Open 5 1/2 inch hole to 7 1/2 inch F/25 ft.T/37 ft.with full returns.Temp out 52 degrees.Circulate hole clean. POOH with 7 1/2 inch bit.Slind loads. Install 2 living coridorrs.Waiting on 9 7/8 inch bit that is in Dutch.Bad weather. Cost/AFE Information AFE No AFE Description AFE Amount Daily Mud Well Mud Daily Total Well Total %Spent No AFE Assigned 0 0 0 16,110 299,809 Totals$: 0 0 0 16,110 299,809 Rig Information Equipment Problems: Location Condition: Transport: Safety Information Meetings/Drills Time Description Safety 15 Pre-tour safety meetings with both crews. First Aid: Medical: Lost Time Accidents: Days Since LTA: 7 BOP Test El Crownamatic Check Weather Information Sky Condition: Fog and Wind Visibility: 0.5 Air Temperature: 52.0 degF Bar.Pressure: Wind Speed/Dir: 15/E Wind Gusts: 20 Printed: 19:50 13-Sep-10 R/MBase 5.1.1.177 Page: 1 of 1 Daily Drilling Report Geothermal Resource Group q0b. Well ID: AGP TG-2 Well Name: Hot Springs Well Field: Hot Springs Bay V8 Sect: 32 Town:69S Rng: 112W County:Aleutians East State:AK Report No: 9 Report For 18-Jul-10 Operator: City of Akutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 37 Drilling Days: 9 actual/22 plan RKB Elevation: 4.00 County: Aleutians East Vertical Depth(ft): 37 Days On Location: 9 Last Casing: 6.675 at 37 Field: Hot Springs Bay Hole Made: 0 Spud Date: 16-Jul-10 Next Casing: 6.625 at 30 Working Interest: Drilling Hrs: 0 Average ROP: 0 Last BOP Test: Personnel: Operator: 2 Contractor: 7 Service: 7 Other: 4 Total: 20 Current Operations: WOC. Installed 6-5/8"riser. Planned Operations: Core ahead 5-1/2"hole to 150'. Toolpusher: David Griggs. Wellsite Supervisors: Randy Baldwin, Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 11:30 11.50 37 WOE Waited on 9-7/8"bit from Dutch Harbor delayed due to weather. Worked on equipment X and camps. 11:30 15:00 3.50 37 OPEN Bit arrived on location.MU bit and opened hole to 9-7/8"t/37'with full returns.Temp out=57 deg F. 15:00 15:30 0.50 37 CIRC Circulated hole clean. 15:30 16:00 0.50 37 TRPO POH&LD bit. 16:00 17:00 1.00 37 CASE Ran 33 ft.of 6 5/8 inch casing.Centered casing using PQ rod with XO. 17:00 19:00 2.00 37 CMTP Ran 1-1/4"PVC tremie pipe to 37'.Mixed and pumped 2-1/2 bbls of 13.5 ppg cement. (50%excess.) CIP at 1900. 19:00 21:00 2.00 37 WOC Wait on cement. 21:00 22:00 1.00 37 CMTS Tagged cement 6 ft.down. Performed top job using 1/2 bbl of 13.5 ppg cement through tremie.CIP at 2200. 22:00 0:00 2.00 37 WOC Wait on cement. _ Management Summary 9-7/8"bit arrived on location at 11:30 hrs. Comments Opened hole to 9-7/8"t/37'with full returns.Ran 33 ft of 6-5/8"20#casing as conductor.Cemented conductor with tremie,WOC&ran top job.WOC. Casing Information Type Size Top MD Top ND Bottom MD Bottom ND Hole Section Avg OH Diam LOT FULL 6.675 4 37 COND Cost/AFE Information AFE No AFE Description AFE Amount Daily Mud Well Mud Daily Total Well Total %Spent No AFE Assigned 0 0 0 14,581 314,390 Totals$: 0 0 0 14,581 314,390 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 0 37 4 9.2 80 9 1 150 0 0 0 0 Jets: 18 18 18 Out: 37 Grade: Cutter: 2/2 Dull: WT/NO Wear:A Brgs: E Gge: 0 Pull: TD Rig Information Equipment Problems: Location Condition: Transport: Safety Information Meetings/Drills Time Description Safety 15 Pre-tour safety meetings with both crew. First Aid: Medical: Lost Time Accidents: Days Since LTA: 8 BOP Test ❑ Crownamatic Check Printed: 19:50 13-Sep-10 RIMBase 5.1.1.177 Page: 1 of 1 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well Field: Hot Springs Bay Va Sect: 32 Town:69S Rng: 112W County:Aleutians East State:AK Report No: 10 Report For 19-Jul-10 Operator: City ofAkutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 115 Drilling Days: 10 actual/22 plan RKB Elevation: 4.00 County: Aleutians East Vertical Depth(ft): 115 Days On Location: 10 Last Casing: 6.675 at 37 Field: Hot Springs Bay Hole Made: 78 Spud Date: 16-Jul-10 Next Casing: 6.625 at 30 Working Interest: Drilling Hrs: 14.0 Average ROP: 5.6 Last BOP Test: Personnel: Operator: 2 Contractor: 7 Service: 4 Other: 4 Total: 17 Current Operations: Took drift shot with MRT-0 deg inc.and 97 deg F.Core ahead f/115't/138'with full returns. Mud temp out 91 deg F. Planned Operations: Continue coring to 150'casing point.Run and cement 4-1/2"HWT casing.Nipple up BOPE. Toolpusher: David Griggs. Wellsite Supervisors: Randy Baldwin, Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 4:00 4.00 37 WOC Waited on cement. 4:00 5:00 1.00 37 OTHER Pumped out cellar&tagged cement 1 foot down.Remove PQ rod and x-over from casing. 5:00 9:00 4.00 37 BOPO MU 6-5/8"riser.Re-installed foot clamp and foot. 9:00 10:00 1.00 37 CIRC Conditioned mud to 8.9 ppg. 10:00 0:00 14.00 115 DRIL Core 5-1/2 inch hole f/37'U115'with full returns. Temp in=57 deg F,Temp out=87 deg F. Management Summary Fines in the mud causing core barrel to become sticky. Comments WOC. MU riser&cored 5-1/2"hole U115'. Casing Information Type Size Top MD Top TVD Bottom MD Bottom ND Hole Section Avg OH Diam LOT FULL 6.675 4 37 COND Cost/AFE Information AFE No AFE Description AFE Amount Daily Mud Well Mud Daily Total Well Total %Spent No AFE Assigned 0 0 0 179,186 493,576 Totals$: 0 0 0 179,186 493,576 Mud Information % Gels Temp Density Vis PV YP Filt. Cake pH Solids Oil Water Sand Chloride Calcium 10s 10m 30m In Out 19-Jul-10 18:00 at Depth 92 ft Sample from Mud Pits,Type:Low Solids Non-Dispersed 8.70 39 10 57 89 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 ADT 2A0 5.500 37 78 14 5.6 9 37 200 Jets: Out: 157 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 37 115 37 37 200 Annular Velocity: Drill Collars: 90.7 Drill Pipe: 90.7 Survey Information Survey Meas. Vertical Coordinates Type Depth Inc. Azimuth ND Closure Section N-S E-W D.L.S. TOTCO 100.0 0.00 0.0 100.0 0.0 0.0 0.000 Printed: 19:50 13-Sep-10 RIMBase 5.1.1.177 Page: 1 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well Field: Hot Springs Bay Va Sect: 32 Town: 69S Rng: 112W County: Aleutians East State:AK Report No: 10 Report For 19-Jul-10 Rig Information Equipment Problems: Location Condition: Transport: Safety Information Meetings/Drills Time Description Safety 15 Pre-tour safety meetings with both crew. First Aid: Medical: Lost Time Accidents: Days Since LTA: 9 ❑ BOP Test ❑ Crownamatic Check Printed: 19:50 13-Sep-10 RIMBase 5.1.1.177 Page:2 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well Field: Hot Springs Bay Va Sect: 32 Town:69S Rng: 112W County:Aleutians East State:AK Report No: 11 Report For 20-Jul-10 Operator: City of Akutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 157 Drilling Days: 11 actual/22 plan RKB Elevation: 4.00 County: Aleutians East Vertical Depth(ft): 157 Days On Location: 11 Last Casing: 4.5 at 157,Test to Field: Hot Springs Bay Hole Made: 42 Spud Date: 16-Jul-10 Next Casing: 3.500 at 600 Working Interest: Drilling Hrs: 11.0 Average ROP: 3.8 Last BOP Test: Personnel: Operator: 2 Contractor: 7 Service: 3 Other: 4 Total: 16 Current Operations: Waited on cement.Removed cement head. Planned Operations: Nipple-up and test BOPE. Toolpusher: David Griggs. Wellsite Supervisors: Randy Baldwin, Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 6:30 6.50 138 DRIL Cored 5-1/2"hole f/115'U138'with full returns.Temp out 81 degrees. 6:30 8:00 1.50 138 CIRC Cleaned mud pits&conditioned mud. 8:00 11:30 3.50 148 DRIL Cored f/138'1/148'with full returns.Temp out 98 degees. 11:30 12:30 1.00 148 TRPO POH to retrieve core-core dropped from barrel due to fines in pipe. 12:30 13:30 1.00 148 TRPI RIH 11148'. 13:30 14:30 1.00 157 DRIL Cored 5-1/2 inch hole f/148'U157'with full returns. 14:30 15:30 1.00 157 CIRC Circulated&conditioned for casing. Ran drift shot w/MRT. 0.75 inc.&173 deg F BHT. 15:30 16:30 1.00 157 TRPO POH with pipe and core barrel. 16:30 20:00 3.50 157 CASE MU and ran 4-1/2"HWT casing. Tack welded float collar above 1st joint. 20:00 21:00 1.00 157 CASE Circulated casing.Temp out= 144 deg F.MU landing joint with cement head.Tagged bottom&pulled up 2'. 21:00 23:00 2.00 157 CMTP Mixed 3.2 bbls of 13.5 ppg cement(100%excess).Pumped 1 bbl of water ahead,3.2 bbls of cement.Dropped plug&displace with 2.25 bbls of water.Bumped plug and checked float. Float held. 23:00 0:00 1.00 157 WOC Wait on cement. Comments Cored 5-1/2"hole f/115'U157'with full returns.Ran and cemented 4-1/2"HWT casing. Casing Information Type Size Top MD Top TVD Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.675 4 37 COND FULL 4.500 3 3 157 157 SURF 5.500 12.00 Cost/AFE Information AFE No AFE Description AFE Amount Daily Mud Well Mud Daily Total Well Total %Spent No AFE Assigned 0 0 0 13,371 506,947 Totals$: 0 0 0 13,371 506,947 Mud Information % Gels Temp Density Vis PV YP Filt. Cake pH Solids Oil Water Sand Chloride Calcium 10s 10m 30m In Out 20-Jul-10 12:00 at Depth 148 ft Sample from Mud Pits,Type:Low Solids Non-Dispersed 8.70 40 10 61 81 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 ADT 2A0 5.500 37 120 24 5.0 9 37 200 Jets: Out: 157 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 115 157 37 37 200 Annular Velocity: Drill Collars: 90.7 Drill Pipe: 90.7 Printed: 19:50 13-Sep-10 RIMBase 5.1.1.177 Page: 1 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well Field: Hot Springs Bay Va Sect: 32 Town: 69S Rng: 112W County: Aleutians East State:AK Report No: 11 Report For 20-Jul-10 Survey Information Survey Meas. Vertical Coordinates Type Depth Inc. Azimuth ND Closure Section N-S E-W D.L.S. TOTCO 157.0 0.75 Rig Information Equipment Problems: Location Condition: Transport: Safety Information Meetings/Drills Time Description Safety 15 Pre-tour with both crews. First Aid: Medical: Lost Time Accidents: Days Since LTA: 10 BOP Test Crownamatic Check Printed: 19:50 13-Sep-10 R/MBase 5.1 1.177 Page 2 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well Field: Hot Springs Bay V2 Sect: 32 Town:69S Rng: 112W County:Aleutians East State:AK Report No: 12 Report For 21-Jul-10 Operator: City of Akutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 157 Drilling Days: 12 actual/22 plan RKB Elevation: 4.00 County: Aleutians East Vertical Depth(ft): 157 Days On Location: 12 Last Casing: 4.5 at 157,Test to Field: Hot Springs Bay Hole Made: 0 Spud Date: 16-Jul-10 Next Casing: 3.500 at 600 Working Interest: Drilling Hrs: 0 Average ROP: 0 Last BOP Test: Personnel: Operator: 2 Contractor: 7 Service: 4 Other: 4 Total: 17 Current Operations: Nippling up BOPE. Planned Operations: Finish nippling up BOPE and test. Perform formation integrity test. Toolpusher: David Griggs. Wellsite Supervisors: Randy Baldwin, Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 6:00 6.00 157 WOC Waited on cement. 6:00 8:00 2.00 157 OTHER Broke out cement head and landing joint. 8:00 16:00 8.00 157 BOPO Weld center ring. Nippled up BOPE. 16:00 18:00 2.00 157 BOPT Function tested annular preventer and pneumatic diverter valve.Tested casing to 650 psi.Leak at the thread on wellhead. 18:00 0:00 6.00 157 BOPND Nippled down BOPE and BakerLok'd wellhead. Comments Waited on cement.Nippled up BOPE.Function and pre-tested BOPE-small leak at wellhead. Nippled down BOPE. Casing Information Type Size Top MD Top TVD Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.675 4 37 COND FULL 4.500 3 3 157 157 SURF 5.500 12.00 Cost/AFE Information AFE No AFE Description AFE Amount Daily Mud Well Mud Daily Total Well Total %Spent No AFE Assigned 0 0 0 28,560 535,507 Totals$: 0 0 0 28,560 535,507 Rig Information Equipment Problems: Location Condition: Transport: Safety Information Meetings/Drills Time Description Safety 15 Pre-tour with both crews. First Aid: Medical: Lost Time Accidents: Days Since LTA: 11 ❑ BOP Test 0 Crownamatic Check Printed: 19:50 13-Sep-10 RIMBase 5.1.1.177 Page: 1 of 1 Daily Drilling Report Geothermal Resource Group q0b6. Well ID: AGP TG-2 Well Name: Hot Springs Well Field: Hot Springs Bay V8 Sect:32 Town: 69S Rng: 112W County:Aleutians East State:AK Report No: 13 Report For 22-Jul-10 Operator: City of Akutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 173 Drilling Days: 13 actual/22 plan RKB Elevation: 4.00 County: Aleutians East Vertical Depth(ft): 173 Days On Location: 13 Last Casing: 4.5 at 157,Test to Field: Hot Springs Bay Hole Made: 16 Spud Date: 16-Jul-10 Next Casing: 3.500 at 600 Working Interest: Drilling Hrs: 5.0 Average ROP: 3.2 Last BOP Test: 22-Jul-10 Personnel: Operator: 2 Contractor: 7 Service: 4 Other: 4 Total: 17 Current Operations: Cored 3-1/2"hole f/173't/225'with full returns. Planned Operations: Core ahead 3-1/2"hole to 600'. Toolpusher: David Griggs. Wellsite Supervisors: Randy Baldwin, Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 14:30 14.50 157 BOPNU Nippled up BOPE. 14:30 18:30 4.00 157 BOPT Tested casing,master valve,pneumatic 3-1/8" 3M diverter valve and kill line to 750 psi.Approx 35 lbs/10 minutes bleed off. Ran test plug&tested annular preventer to -� 750 psi.Tested accumulator and LEL alarms. Tests approved as per inspector Jeff Jones,AOGCC. 18:30 23:30 5.00 173 DRIL RIH. Drill out float collar and shoe track.Cored 3-1/2"hole t1173'with full returns.Temp out 88 degrees. 23:30 0:00 0.50 173 FIT Circulated hole clean.Closed bag and performed formation integrity test with 8.5#mud in hole to 32 psi. (0.625 psi/12 ppg equivalent.) Comments Nippled up BOPE.Tested casing,master valve,diverter valves,annular prevent,and kill line to 750 psi. Tested accumulator and LEL alarms. Drill out float collar and shoe track.Cored 3-1/2"hole to 173'with full returns.Temp out 88 degrees. Performed FIT. Casing Information Type Size Top MD Top ND Bottom MD Bottom ND Hole Section Avg OH Diam LOT FULL 6.675 4 37 COND FULL 4.500 3 3 157 157 SURF 5.500 12.00 Cost/AFE Information AFE No AFE Description AFE Amount Daily Mud Well Mud Daily Total Well Total %Spent No AFE Assigned 0 0 0 13,830 549,337 Totals$: 0 0 0 13,830 549,337 Mud Information Gels Temp Density Vis PV YP Filt. Cake pH Solids Oil Water Sand Chloride Calcium 10s 10m 30m In Out 22-Jul-10 17:00 at Depth 157 ft Sample from Mud Pits,Type:Low Solids Non-Dispersed 8.50 32 9 57 81 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 ATCOP Hobic 6 3.830 157 16 0.5 32.0 9 37 160 Jets: Out: 223 Grade: Cutter: 4/3 Dull: WT/NO Wear: Brgs: Gge: 0 Pull: TQ 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 157 173 32.0 37 37 160 Annular Velocity: Drill Collars: 332.6 Drill Pipe: 332.6 Rig Information Equipment Problems: Location Condition: Transport: Printed: 19:50 13-Sep-10 RIMBase 5.1.1.177 Page:1 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well Field: Hot Springs Bay Ve Sect: 32 Town: 69S Rng: 112W County:Aleutians East State:AK Report No: 13 Report For 22-Jul-10 Safety Information Meetings/Drills Time Description Safety 15 Pre-tour with both crews, BOP 120 First Aid: Medical: Lost Time Accidents: Days Since LTA: 12 Q✓ BOP Test Crownamatic Check Printed: 19:50 13-Sep-10 RIMBase 5.1.1.177 Page:2 of 2 Daily Drilling Report Geothermal Resource Group N07 Well ID: AGP TG-2 Well Name: Hot Springs Well Field: Hot Springs Bay V2 Sect: 32 Town:69S Rng: 112W County:Aleutians East State:AK Report No: 14 Report For 23-Jul-10 Operator: City of Akutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 281 Drilling Days: 14 actual/22 plan RKB Elevation: 4.00 County: Aleutians East Vertical Depth(ft): 281 Days On Location: 14 Last Casing: 4.5 at 157,Test to Field: Hot Springs Bay Hole Made: 108 Spud Date: 16-Jul-10 Next Casing: 3.500 at 600 Working Interest: Drilling Hrs: 14.5 Average ROP: 7.4 Last BOP Test: 22-Jul-10 Personnel: Operator: 2 Contractor: 7 Service: 4 Other: 4 Total: 17 Current Operations: Cored 3-1/2"hole f/281'1/312'with full returns. Planned Operations: Core ahead 3-1/2"hole to 600'. Toolpusher: David Griggs. Wellsite Supervisors: Randy Baldwin, Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations DescriptionNon-Prod 0:00 6:30 6.50 223 DRIL Cored 3-1/2"hole f/157'1/223'with full returns.Temp out=94 deg F. 6:30 7:00 0.50 223 TRPO POH out due to high torque. 7:00 9:00 2.00 223 TRPI MU new bit and reamer,checked LELs in cellar.RIH t/223'. 9:00 10:00 1.00 241 DRIL Cored 3-1/2"hole f/223'1/241'with full returns.Temp out=94 deg F. 10:00 10:30 0.50 241 TRPO Worked stuck tube. POH to 160'.Well started flowing.Conditioned mud to 8.7 ppg. Finished POH. 10:30 11:00 0.50 241 CIRC RIH to 241'. 11:00 11:30 0.50 241 SURV Circulated hole. Ran drift shot with MRT at 241'. 2.25 deg inc, 234 deg F. 11:30 15:30 4.00 256 DRIL Cored 3-1/2"hole f/241'11256'with full returns.Temp out=94 deg F. 15:30 16:00 0.50 256 TRPO POH due to stuck tube.Barite causing cake inside of rods. 16:00 17:30 1.50 256 OTHER Pressure wash barite from inside of rods and outside of core barrel.Condition mud to 8.6 ppg. 17:30 18:30 1.00 256 TRPI RIH to 256'. 18:30 21:00 2.50 271 DRIL Cored 3-1/2"hole f/256'1/271'with full returns.Temp out=94 deg F. Check LELs in cellar. 21:00 22:00 1.00 271 TRPO POH for stuck tube. 22:00 22:30 0.50 271 REPR Repaired inner tube. X 22:30 23:30 1.00 271 TRPI RIH 1/271'. 23:30 0:00 0.50 281 DRIL Cored 3-1/2"hole f/271'11281'with full returns.Temp out=94 deg F. Ran MRT at 281',273 deg F. v Comments Cored 3-1/2"hole f/157'U241'with full returns.Tripped for bit. Well flowed while tripping.Cored 3-1/2"hole f/241'U281'with full returns. Casing Information Type Size Top MD Top TVD Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.675 4 37 COND FULL 4.500 3 3 157 157 SURF 5.500 12.00 Cost/AFE Information AFE No AFE Description AFE Amount Daily Mud Well Mud Daily Total Well Total %Spent No AFE Assigned 0 0 0 15,442 564,779 Totals$: 0 0 0 15,442 564,779 Mud Information Gels Temp Density Vis PV YP Filt. Cake pH Solids Oil Water Sand Chloride Calcium 10s 10m 30m In Out 23-Jul-10 17:00 at Depth 256 ft Sample from Mud Pits,Type:Low Solids Non-Dispersed 8.60 36 9.5 80 98 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 ATCOP Hobic 6 3.830 157 124 13.5 9.2 1200 9 37 200 Jets: Out: 223 Grade: Cutter: 4/3 Dull: WT/NO Wear: Brgs: Gge: 0 Pull: TQ Printed: 19:50 13-Sep-10 RIMBase 5.1.1.177 Page: 1 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG 2 Well Name: Hot Springs Well Field: Hot Springs Bay V2 Sect: 32 Town: 69S Rng: 112W County:Aleutians East State:AK Report No: 14 Report For 23-Jul-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 223 281 1200 37 37 150 Annular Velocity: Drill Collars: 444.9 Drill Pipe: 444.9 173 223 1200 37 37 150 Annular Velocity: Drill Collars: 444.9 Drill Pipe: 444.9 Comments: Trip for bit#5 at 223'. Survey Information Survey Meas. Vertical Coordinates Type Depth Inc. Azimuth TVD Closure Section N-S E-W D.L.S. TOTCO 241.0 2.25 Rig Information Equipment Problems: Location Condition: Transport: Safety Information Meetings/Drills Time Description Safety 15 Pre-tour with both crews. First Aid: Medical: Lost Time Accidents: Days Since LTA: 13 111 BOP Test 0 Crownamatic Check Printed: 19:50 13-Sep-10 RIMBase 5.1.1.177 Page:2 of 2 1 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well Field: Hot Springs Bay Va Sect 32 Town:69S Rng: 112W County:Aleutians East State:AK Report No: 15 Report For 24-Jul-10 Operator: City of Akutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 470 Drilling Days: 15 actual/22 plan RKB Elevation: 4.00 County: Aleutians East Vertical Depth(ft): 470 Days On Location: 15 Last Casing: 4.5 at 157,Test to Field: Hot Springs Bay Hole Made: 189 Spud Date: 16-Jul-10 Next Casing: 3.500 at 600 Working Interest: Drilling Hrs: 19.5 Average ROP: 9.7 Last BOP Test: 22-Jul-10 Personnel: Operator: 2 Contractor: 7 Service: 4 Other: 4 Total: 17 Current Operations: Openen bag&finished POH with core barrel.RIH t/20'with water swivel while repairing core barrel.RIH with bit,reamer, and core barrel to 470'.Circulated and conditioned mud.Bottoms-up temp=136 deg F. Cored 1/499 ft. Planned Operations: Core ahead to 600 ft. Toolpusher: David Griggs. Wellsite Supervisors: Randy Baldwin, Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 5:00 5.00 312 DRIL Cored 3-1/2"hole f/281 t/312'with full returns.Temp out=104 deg F Ran MRT= 212 deg F. 5:00 6:30 1.50 322 DRIL Cored 3-1/2"hole f/312't/322'with full returns.Temp out=94 deg F Ran MRT=216 deg F 6:30 10:30 4.00 339 DRIL Cored 3-1/2"hole f/322't/339'with full returns.Temp out=116 deg F Ran MRT=180 deg F.Checked LELs in cellar 0800. 10:30 12:00 1.50 370 DRIL Cored 3-1/2"hole f/339'11370'with full returns.Temp out=90 deg F 12:00 12:30 0.50 370 SURV Ran drift shot with MRT at 370'. 1.75 deg inc, 226 deg F. 12:30 13:40 1.17 400 DRIL Cored 3-1/2"hole f/370'1/400'with full returns.Temp out= 117 deg F Ran MRT=163 deg F. 13:40 15:30 1.83 430 DRIL Cored 3-1/2"hole f/400'11430'with full returns.Temp out= 105 deg F Ran MRT=171 deg F. 15:30 18:40 3.17 469 DRIL Cored 3-1/2"hole f/430'11469'with full returns.Temp out= 103 deg F Ran MRT=234 deg F. 18:40 20:00 1.33 470 DRIL Cored 3-1/2"hole f/469't/470'with full returns.Temp out=93 deg F Checked LELs in cellar. 20:00 21:00 1.00 470 TRPO Circ.and clean hole.POH due to high torque and pressure.At 13'the well began r' flowing.Inner tube became stuck part way up in core barrel. 21:00 0:00 3.00 470 KILL Hot water camed up annulus.Closed annular preventer.Opened 3 inch manual X diverter valve.Opened 3 inch pneumatic diverter valve, Well flowed at an estimated 120 gals/min.Closed pnematic diverter valve.Mixed bar to 10 ppg mud and killed well. „ Comments Cored 3-1/2"hole f/281't/470'with full returns.Ran MRTs approx every 30 ft. POH due to high torque and pressure.Well began flowing with bit at 13'.Mixed and pump 10 ppg mud and killed well. Casing Information Type Size Top MD Top TVD Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.675 4 37 COND FULL 4.500 3 3 157 157 SURF 5.500 12.00 Cost/AFE Information AFE No AFE Description AFE Amount Daily Mud Well Mud Daily Total Well Total %Spent No AFE Assigned 0 0 0 68,660 633,439 Totals$: 0 0 0 68,660 633,439 Mud Information Gels Temp Density Vis PV YP Filt. Cake pH Solids Oil Water Sand Chloride Calcium 10s 10m 30m In Out 24-Jul-10 17:00 at Depth 460 ft Sample from Mud Pits,Type:Low Solids Non-Dispersed 8.50 36 10 88 115 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 ADT 8DM 3.870 223 109 19.5 5.6 9 70 200 Jets: Out: 613 Grade: Cutter: 2/2 Dull: WT/NO Wear: A Brgs:X Gge: 0 Pull: TD Printed: 19:50 13-Sep-10 RIMBase 5.1.1.177 Page: 1 of 2 "x „ Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well Field: Hot Springs Bay V2 Sect: 32 Town: 69S Rng: 112W County:Aleutians East State:AK Report No: 15 Report For 24-Jul-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 281 479 1100 1200 70 70 200 Annular Velocity: Drill Collars: 629.2 Drill Pipe: 629.2 Comments: Using both mud pumps. Rig Information Equipment Problems: Location Condition: Transport: Safety Information Meetings/Drills Time Description Safety 15 Pre-tour with both crews, First Aid: Medical: Lost Time Accidents: Days Since LTA: 14 0 BOP Test [] Crownamatic Check Printed: 19:50 13-Sep-10 RIMBase 5.1.1.177 Page:2 of 2 Daily Drilling Report Geothermal Resource Group I:* Well ID: AGP TG-2 Well Name: Hot Springs Well Field: Hot Springs Bay Va Sect: 32 Town: 69S Rng: 112W County:Aleutians East State:AK Report No: 16 Report For 25-Jul-10 Operator: City ofAkutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 503 Drilling Days: 16 actual/22 plan RKB Elevation: 4.00 County: Aleutians East Vertical Depth(ft): 503 Days On Location: 16 Last Casing: 4.5 at 157,Test to Field: Hot Springs Bay Hole Made: 33 Spud Date: 16-Jul-10 Next Casing: 3.500 at 600 Working Interest: Drilling Hrs: 3.5 Average ROP: 9.4 Last BOP Test: 22-Jul-10 Personnel: Operator: 2 Contractor: 7 Service: 4 Other: 4 Total: 17 Current Operations: Wait on repair parts. Planned Operations: Make repairs and core ahead. Toolpusher: David Griggs. Wellsite Supervisors: Randy Baldwin, Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 2:30 2.50 470 TRPI Opened bag.POH with core barrel and inner tube.MU core barrel and RIH T/470'. Hole stayed full. 2:30 6:00 3.50 503 DRIL Cored 3-1/2"hole f/470't/503'with full returns. Temp out=130 deg F. 6:00 8:00 2.00 503 OTHER Attempted to pull tube.Inner barrel stuck. Conditioned mud.Attempted to pull tube again. Checked LELs in cellar at 08:00. 8:00 12:00 4.00 503 REPR Attempted to POH.Jaws in head would not grip pipe.Disassembled head and X discovered damage.Ordered parts to fix. 12:00 0:00 12.00 503 WOE Waited on parts.Circulated hole. Temp out= 122 deg F. Checked LELs in cellar at X 20:00. Comments RIH&cored 3-1/2"hole f/470't/503'with full returns. Inner core barrel stuck.Attempted to POH.Jaws in head broken. Waited on parts. Casing Information Type Size Top MD Top ND Bottom MD Bottom ND Hole Section Avg OH Diam LOT FULL 6.675 4 37 COND FULL 4.500 3 3 157 157 SURF 5.500 12.00 Cost/AFE Information AFE No AFE Description AFE Amount Daily Mud Well Mud Daily Total Well Total %Spent No AFE Assigned 0 0 0 7,380 640,819 Totals$: 0 0 0 7,380 640,819 Mud Information Gels Temp Density Vis PV YP Flit. Cake pH Solids Oil Water Sand Chloride Calcium 10s 10m 30m In Out 25-Jul-10 17:00 at Depth 503 ft Sample from Mud Pits,Type:Low Solids Non-Dispersed 8.50 35 10 88 125 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 ADT 8DM 3.870 223 142 23 6.2 9 70 250 Jets: Out: 613 Grade: Cutter: 2/2 Dull: WT/NO Wear:A Brgs:X Gge: 0 Pull:TD 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 470 503 6.0 1100 1200 70 70 250 Annular Velocity: Drill Collars: 629.2 Drill Pipe: 629.2 Comments: Using both mud pumps. Rig Information Equipment Problems: 5 of the 7 nitorgen impellers that hold down jaws on chuck are bad. Location Condition: Transport: Printed: 19:50 13-Sep-10 RIMBase 5.1.1.177 Page: 1 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well Field: Hot Springs Bay V8 Sect: 32 Town: 69S Rng: 112W County:Aleutians East State:AK Report No: 16 Report For 25-Jul-10 Safety Information Meetings/Drills Time Description Safety 15 Pre=tour with both crews. First Aid: Medical: Lost Time Accidents: Days Since LTA: 15 BOP Test Crownamatic Check Weather Information Sky Condition: Visibility: Air Temperature: Bar.Pressure: Wind Speed/Dir: / Wind Gusts: Printed: 19:50 13-Sep-10 RIMBase 5.1.1.177 Page:2 of 2 Daily Drilling Report Geothermal Resource Group qb0 Well ID: AGP TG-2 Well Name: Hot Springs Well Field: Hot Springs Bay V2 Sect: 32 Town:69S Rng: 112W County:Aleutians East State:AK Report No: 17 Report For 26-Jul-10 Operator: City of Akutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 503 Drilling Days: 17 actual/22 plan RKB Elevation: 4.00 County: Aleutians East Vertical Depth(ft): 503 Days On Location: 17 Last Casing: 4.5 at 157,Test to Field: Hot Springs Bay Hole Made: 0 Spud Date: 16-Jul-10 Next Casing: 3.500 at 600 Working Interest: Drilling Hrs: 0 Average ROP: 0 Last BOP Test: 22-Jul-10 Personnel: Operator: 2 Contractor: 7 Service: 4 Other: 4 Total: 17 Current Operations: Waited on parts.Circulated hole. Temp out= 128 deg F. Planned Operations: Make repairs on rig and core ahead to 600'. Toolpusher: David Griggs. Wellsite Supervisors: Randy Baldwin, Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 0:00 24.00 503 REPR Waited on parts.Circulated hole. Temp out=128 deg F. Checked LELs in cellar at X 06:00 and 20:00. Comments Waited on parts.Circulated hole. Temp out= 128 deg F. Casing Information Type Size Top MD Top TVD Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.675 4 37 COND FULL 4.500 3 3 157 157 SURF 5.500 12.00 Cost/AFE Information AFE No AFE Description AFE Amount Daily Mud Well Mud Daily Total Well Total %Spent No AFE Assigned 0 0 0 4,905 645,724 Totals$: 0 0 0 4,905 645,724 Mud Information Gels Temp Density Vis PV YP Filt. Cake pH Solids Oil Water Sand Chloride Calcium 10s 10m 30m In Out 26-Jul-10 17:00 at Depth 503 ft Sample from Mud Pits,Type:Low Solids Non-Dispersed 8.50 34 10 90 128 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 ADT 8DM 3.870 223 142 23 0.0 0.0 0 0 0 9 35 200 Jets: Out 613 Grade: Cutter: 2/2 Dull. WT/NO Wear:A Brgs:X Gge: 0 Pull: TD Rig Information Equipment Problems: 5 of the 7 nitorgen impellers that hold down jaws on chuck are bad.Jaws wont grip the pipe. Location Condition: Transport: Safety Information Meetings/Drills Time Description Safety 15 Pre-tour with both crews. First Aid: Medical: Lost Time Accidents: 1 Days Since LTA: 16 Accident Description: Person holding 36 inch pipe wrench to tighten water swivel,pulled his muscle in his right shoulder. ❑ BOP Test Crownamatic Check Weather Information Sky Condition: Visibility: Air Temperature: Bar.Pressure: Wind Speed/Dir: / Wind Gusts: Printed: 19:50 13-Sep-10 RIMBase 5.1.1.177 Page: 1 of 1 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well Field: Hot Springs Bay V2 Sect: 32 Town:69S Rng: 112W County:Aleutians East State:AK Report No: 18 Report For 27-Jul-10 Operator: City of Akutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 503 Drilling Days: 18 actual/22 plan RKB Elevation: 4.00 County: Aleutians East Vertical Depth(ft): 503 Days On Location: 18 Last Casing: 4.5 at 157,Test to Field: Hot Springs Bay Hole Made: 0 Spud Date: 16-Jul-10 Next Casing: 3.500 at 600 Working Interest: Drilling Hrs: 0 Average ROP: 0 Last BOP Test: 22-Jul-10 Personnel: Operator: 2 Contractor: 7 Service: 4 Other: 4 Total: 17 Current Operations: Waited on parts.Circulated hole. Temp out= 118 deg F. Planned Operations: Make repairs on rig and core ahead to 600'. Toolpusher: David Griggs. Wellsite Supervisors: Randy Baldwin, Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 0:00 24.00 503 REPR Waited on parts.Circulated hole. Temp out= 118 deg F. Rig parts made it to Dutch X Harbor.Helocopper went to get parts,engine light came on.Check LELs in cellar at 06:00 and 20:00. Comments Waited on parts.Circulated hole. Temp out=118 deg F. (Temp coming down due to winds across sump.) Casing Information Type Size Top MD Top ND Bottom MD Bottom ND Hole Section Avg OH Diam LOT FULL 6.675 4 37 COND FULL 4.500 3 3 157 157 SURF 5.500 12.00 Cost/AFE Information AFE No AFE Description AFE Amount Daily Mud Well Mud Daily Total Well Total %Spent No AFE Assigned 0 0 0 4,906 650,630 Totals$: 0 0 0 4,906 650,630 Mud Information Gels Temp Density Vis PV YP Filt. Cake pH Solids Oil Water Sand Chloride Calcium 10s 10m 30m In Out 27-Jul-10 17:00 at Depth 503 ft Sample from Mud Pits,Type:Low Solids Non-Dispersed 8.50 34 10 75 115 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 ADT 8DM 3.870 223 142 23 9 35 175 Jets: Out: 613 Grade: Cutter: 2/2 Dull: WT/NO Wear: A Brgs:X Gge: 0 Pull: TD Rig Information Equipment Problems: 5 of the 7 nitorgen impellers that hold down jaws on chuck are bad.Jaws wont grip the pipe. Location Condition: Transport: Safety Information Meetings/Drills Time Description Safety 15 Pre-tour with both crews. First Aid: Medical: Lost Time Accidents: Days Since LTA: 17 BOP Test Crownamatic Check Printed: 19:50 13-Sep-10 RIMBase 5.1.1.177 Page: 1 of 1 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well Field: Hot Springs Bay Va Sect: 32 Town:69S Rng: 112W County:Aleutians East State:AK Report No: 19 Report For 28-Jul-10 Operator: City of Akutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 613 Drilling Days: 19 actual/22 plan RKB Elevation: 4.00 County: Aleutians East Vertical Depth(ft): 613 Days On Location: 19 Last Casing: 4.5 at 157,Test to Field: Hot Springs Bay Hole Made: 110 Spud Date: 16-Jul-10 Next Casing: 3.500 at 600 Working Interest: Drilling Hrs: 9.5 Average ROP: 11.6 Last BOP Test: 22-Jul-10 Personnel: Operator: 2 Contractor: 7 Service: 4 Other: 4 Total: 17 Current Operations: RIH with 3 1/2 inch casing t/603 ft.Cemented casing,bump plug.CIP at 0430.WOC. Planned Operations: Test cement.Test BOPs. Pick up NQ rods. Toolpusher: David Griggs. Wellsite Supervisors: Randy Baldwin, Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 8:00 8.00 503 REPR Waited on parts from Dutch Harbor. Circulated hole. Temp out= 100 deg F Check X LEL levels in cellar. 8:00 10:30 2.50 523 DRIL Install parts, Cored 3-1/2"hole f/503't/523'with full returns. Temp in 77 deg f.Temp out= 107 deg F. MRT=169 deg F. 10:30 12:00 1.50 553 DRIL Cored 3-1/2"hole f/523't1553'with full returns. Temp out=80 deg F. 12:00 12:30 0.50 553 SURV Ran drift shot with MRT at 553'. 3.75 deg inc, 187 deg F 12:30 14:00 1.50 583 DRIL Cored 3-1/2"hole f/553't/583'with full returns. Temp out= 100 deg F. MRT=169 deg F. 14:00 15:00 1.00 593 DRIL Cored 3-1/2"hole f/583 t/593' lost all returns at 590 ft.. MRT=169 deg F. 15:00 16:00 1.00 593 OTHER Let well heat up. 16:00 17:00 1.00 593 KILL Ran MRT with lubricator.Well started flowing. Let well flow for 10 minutes to get water sample.Close in and kill well.Had 203 deg F at surface with about 1 bbl/min flow. MRT=359 deg F. • 17:00 20:00 3.00 613 DRIL Cored 3-1/2"hole f/593 t/613' with no returns.Check LEL levels in cellar. 20:00 21:30 1.50 613 WOO Wait on orders. X 21:30 22:00 0.50 613 KILL Pump 8.5 ppg mud down drill pipe,and 8.9 ppg mud down annulus. 22:00 0:00 2.00 613 TRPO POH with rods and core barrel with bit. Comments Waited on parts.Cored 3-1/2"hole f/503 t/593' lost all returns at 590 ft.Ran MRT. Well started flowing. Let well flow for 10 minutes and obtained a water sample.Closed in and killed well. Had 203 deg F at surface with about 1 bbl/min flow. MRT=359 deg F.Cored 3-1/2"hole f/593 t/613' with no returns.POH. Casing Information Type Size Top MD Top TVD Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.675 4 37 COND FULL 4.500 3 3 157 157 SURF 5.500 12.00 FULL 3.500 -3 604 3.870 Cost/AFE Information AFE No AFE Description AFE Amount Daily Mud Well Mud Daily Total Well Total %Spent No AFE Assigned 0 0 0 20,280 670,910 Totals$: 0 0 0 20,280 670,910 Mud Information Gels Temp Density Vis PV YP Filt. Cake pH Solids Oil Water Sand Chloride Calcium 10s 10m 30m In Out 28-Jul-10 15:00 at Depth 590 ft Sample from Mud Pits,Type:Low Solids Non-Dispersed 8.50 36 10 78 110 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 ADT 8DM 3.870 223 252 32.5 7.8 1100 9 70 120 Jets: Out: 613 Grade: Cutter: 2/2 Dull: WT/NO Wear: A Brgs:X Gge: 0 Pull: TD Printed: 19:50 13-Sep-10 RIMBase 5.1.1.177 Page: 1 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well Field: Hot Springs Bay Va Sect: 32 Town: 69S Rng: 112W County: Aleutians East State:AK Report No: 19 Report For 28-Jul-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 503 613 1100 1200 70 70 100 Annular Velocity: Drill Collars: 629.2 Drill Pipe: 629.2 Comments: Lost returns at 590 ft. Rig Information Equipment Problems: 5 of the 7 nitorgen impellers that hold down jaws on chuck are bad.Jaws wont grip the pipe. Location Condition: Transport: Safety Information Meetings/Drills Time Description Safety 15 Pre-tour with both crews. First Aid: Medical: Lost Time Accidents: Days Since LTA: 18 111 BOP Test ❑ Crownamatic Check Printed: 19:50 13-Sep-10 RIMBase 5.1.1.177 Page:2 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well Field: Hot Springs Bay Va Sect:32 Town:69S Rng: 112W County:Aleutians East State:AK Report No: 20 Report For 29-Jul-10 Operator: City of Akutan Rig: Major LF90Proposed TD: 1,500 State: AK Measured Depth(ft): 613 Drilling Days: 20 actual/22 plan RKB Elevation: 4.00 County: Aleutians East Vertical Depth(ft): 613 Days On Location: 20 Last Casing: 3.5 at 604 Field: Hot Springs Bay Hole Made: 0 Spud Date: 16-Jul-10 Next Casing: 1.660 at 1,500 Working Interest: Drilling Hrs: 0 Average ROP: 0 Last BOP Test: 22-Jul-10 Personnel: Operator: 2 Contractor: 7 Service: 4 Other: 4 Total: 17 Current Operations: Tested BOPs. Planned Operations: Finish testing BOPs. Core ahead. Toolpusher: David Griggs. Wellsite Supervisors: Randy Baldwin, Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 2:30 2.50 613 TRPI RIH with 603'of 3-1/2"7.7#casing with float collar 10 ft.up. Nipple down 3M pneumatic valve. 2:30 4:30 2.00 613 CMTP Pumped 1 bbl of water ahead.mixed and pump 3.9 bbls of 13.5 ppg cement,dropped plug,and displaced with 5.5 bbls of water.Bumped plug and checked float-float held. No returns throughout job.CIP 0430. 4:30 11:30 7.00 613 WOC Waited on cement.Washed up cement equipment.MU 1000 ft.of N rods in 20 ft. lengths. 11:30 12:00 0.50 613 OTHER Pumped 1 bbl of water to wash down annulus at 60 psi. 12:00 12:30 0.50 613 BOPT Tested casing t/750 psi. 12:30 13:15 0.75 613 CMTS Mixed and circulated 2.8 bbls of 13.5 ppg cement as top job. Started at 80 psi, dropped to 40 psi,and built up to 130 psi.CIP 13:30.Flushed stack. 13:15 13:30 0.25 613 TRPO POOH with 10 ft.landing joint. Closed master valve and wing valve.Monitored pressure through kill line. 13:30 22:00 8.50 613 WOC Waited on cement. Nippled up 3M pneumatic valve. 22:00 0:00 2.00 613 BOPT Tested master valve,outside wing valve,and kill line to 200 psi.and again to to 750 psi.Master valve leaked. Removed pitcher nipple and wash inside of master valve with pressure washer. Comments Ran and cement 603 ft.of 3-1/2"casing.CIP @ 04:30. WOC.Washed annulus with fresh water and performed top job.CIP @ 13:30 WOC.Nlppled up BOP. Began testing BOPE. Casing Information Type Size Top MD Top TVD Bottom MD Bottom ND Hole Section Avg OH Diam LOT FULL 6.675 4 37 COND FULL 4.500 3 3 157 157 SURF 5.500 12.00 FULL 3.500 -3 604 3.870 Cost/AFE Information AFE No AFE Description AFE Amount Daily Mud Well Mud Daily Total Well Total %Spent No AFE Assigned 0 0 0 35,882 706,792 Totals$: 0 0 0 35,882 706,792 Survey Information Survey Meas. Vertical Coordinates Type Depth Inc. Azimuth ND Closure Section N-S E-W D.L.S. TOTCO 370.0 1.75 TOTCO 469.0 2.25 TOTCO 553.0 3.75 Rig Information Equipment Problems: Location Condition: Transport: Printed: 19:50 13-Sep-10 RIMBase 5.1.1.177 Page: 1 of 2 Daily Drilling Report Geothermal Resource Group 1Z.$6* Well ID: AGP TG-2 Well Name: Hot Springs Well Field: Hot Springs Bay Va Sect: 32 Town: 69S Rng: 112W County:Aleutians East State:AK Report No: 20 Report For 29-Jul-10 Safety Information MeetingslDrills Time Description Safety 15 Pre-tour with both crews. First Aid: Medical: Lost Time Accidents: Days Since LTA: 19 BOP Test Crownamatic Check Printed: 19:50 13-Sep-10 R/MBase 5.1.1.177 Page:2 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well Field: Hot Springs Bay Va Sect:32 Town:69S Rng: 112W County:Aleutians East State:AK Report No: 21 Report For 30-Jul-10 Operator: City of Akutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 613 Drilling Days: 21 actual/22 plan RKB Elevation: 4.00 County: Aleutians East Vertical Depth(ft): 613 Days On Location: 21 Last Casing: 3.5 at 604 Field: Hot Springs Bay Hole Made: 0 Spud Date: 16-Jul-10 Next Casing: 1.660 at 1,500 Working Interest: Drilling Hrs: 0 Average ROP: 0 Last BOP Test: 22-Jul-10 Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 4 Total: 18 Current Operations: Nippled down and inspected BOPS. Planned Operations: Continue inspecting BOPs. Install and test BOPs. Toolpusher: David Griggs. Wellsite Supervisors: Randy Baldwin, Dan Darnell Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 5:00 5.00 613 BOPT Attempedt to pressure test BOPS. Still leaking. 5:00 8:00 3.00 613 TRPI Changed over to NQ rods and RIH U 300 ft. 8:00 8:30 0.50 613 COOL Pump 2 bbls of water down drill pipe. 8:30 12:00 3.50 613 TRPO Attempted to close hydrill. Accumulator pump not working. Disasembled gear box on pump. Teeth missing on gears. Ordered replacement. 12:00 16:00 4.00 613 BOPT Attempted to test BOPs,still leaking. No surface leaks visible. 16:00 19:00 3.00 613 CMTS Mixed 1 sack of cement and attempted to squeeze 3-1/2 inch annulus. 19:00 0:00 5.00 613 CMTS Mixed 1 sack of cement with 3%CaCl2 and attempted to squeeze annulus. Comments Attempted to test BOPE. RIH U300'.Attempted to test with water.Gear box on accumulator failed.POH.Attempted to test master valve,kill line and diverter valves.Squeezed 3-1/2"annulus with cement. Casing Information Type Size Top MD Top ND Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.675 4 37 COND FULL 4.500 3 3 157 157 SURF 5.500 12.00 FULL 3.500 -3 604 3.870 Cost/AFEInformation AFE No AFE Description AFE Amount Daily Mud Well Mud Daily Total Well Total %Spent No AFE Assigned 0 0 0 15,510 722,302 Totals$: 0 0 0 15,510 722,302 Rig Information Equipment Problems: Gears on accumulator have numerous missing teeth. Replacement parts have been ordered and shipped. Location Condition: Transport: Safety Information Meetings/Drills Time Description Safety 15 Pre-tour with both crews, First Aid: Medical: Lost Time Accidents: Days Since LTA: 20 ❑ BOP Test ❑ Crownamatic Check Printed: 19:50 13-Sep-10 R/MBase 5.1.1.177 Page: 1 of 1 Daily Drilling Report Geothermal Resource Group l'4r0 Well ID: AGP TG-2 Well Name: Hot Springs Well Field: Hot Springs Bay Va Sect:32 Town:69S Rng: 112W County:Aleutians East State:AK Report No: 22 Report For 31-Jul-10 Operator: City ofAkutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 613 Drilling Days: 22 actual/22 plan RKB Elevation: 4.00 County: Aleutians East Vertical Depth(ft): 613 Days On Location: 22 Last Casing: 3.5 at 604 Field: Hot Springs Bay Hole Made: 0 Spud Date: 16-Jul-10 Next Casing: 1.660 at 1,500 Working Interest: Drilling Hrs: 0 Average ROP: 0 Last BOP Test: 31-Jul-10 Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 4 Total: 18 Current Operations: Ran in the hole and tagged TOC @ 581'.Cleaned out cement f/581'to 583'before the string plugged. POH&checked tools.RIH @ 06:00 hrs. Planned Operations: Clean out float and test casing. Core 20'below shoe and perform leakoff test. Toolpusher: David Griggs. Wellsite Supervisors: Dan Darnell Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 3:00 3.00 613 WOC Waited on cement, 3:00 8:00 5.00 613 BOPND Nippled down BOPE,(note,Cellar was tested for LEL/H2s before nippling down,0 X Pm) 8:00 10:00 2.00 613 BOPO Cleaned and checked all API ring,flange faces,and inspect well head seal assembly, X 10:00 15:00 5.00 613 BOPNU Installed new 0 ring's on test plug,checked seal area and installed.Replaced API X rings on all BOPE.Repaired accumalator and tested. 15:00 18:00 3.00 613 BOPT Pretested and changed out washed valves on mud pump#1 X 18:00 19:30 1.50 613 BOPT Ran test plug and tested between the Master valve and pneumatic valve at 250 psi and 750 psi for 30 min each.Good tests. 19:30 20:30 1.00 613 BOPT Tested between master valve and 3-1/8"manual at 250 psi-750 psi for 30 minutes each. Good tests. 20:30 22:00 1.50 613 BOPNU Nippled up annular preventer and function tested. Installed test plug and tested annular preventer at 250 psi and 750 psi.Good tests. 22:00 0:00 2.00 613 TRPI Made up 3.062"F6M core bit#6 on NQ 2.75 pipe and RIH Comments Waited on cement. Nippled down BOPE and cleaned all flange faces. Replaced API rings. Nippled up and tested BOPE-tests were successful. Made up NQ tools and RIH. Casing Information Type Size Top MD Top ND Bottom MD Bottom ND Hole Section Avg OH Diam LOT FULL 6.675 4 37 COND FULL 4.500 3 3 157 157 SURF 5.500 12.00 FULL 3.500 -3 604 3.870 Cost/AFE Information AFE No AFE Description AFE Amount Daily Mud Well Mud Daily Total Well Total %Spent No AFE Assigned 0 0 0 14,500 736,802 Totals$: 0 0 0 14,500 736,802 Mud Information % Gels Temp Density Vis PV YP Filt. Cake pH Solids Oil Water Sand Chloride Calcium 10s 10m 30m In Out 31-Jul-10 22:00 804.00 32 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 FORDIF F6M 3.062 613 Jets: Out: 671 Grade: Cutter: / Dull / Wear: Brgs: Gge: Pull: PR Rig Information Equipment Problems: Replaced parts on accumulator and tested, Changed out washed valves on pump#1. Location Condition: muddy Transport: Printed: 19:50 13-Sep-10 R/MBase 5.1.1.177 Page:1 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well Field: Hot Springs Bay Va Sect: 32 Town: 69S Rng: 112W County: Aleutians East State:AK Report No: 22 Report For 31-Jul-10 Safety Information Meetings/Drills Time Description Safety 30 Safety meeting held with both crews First Aid: Medical: Lost Time Accidents: Days Since LTA: 21 Q✓ BOP Test Crownamatic Check Weather Information Sky Condition: Rain Visibility: Air Temperature: 62.0 degF Bar.Pressure: Wind Speed/Dir: 37/ Wind Gusts: Printed: 19:50 13-Sep-10 RIMBase 5.1.1.177 Page:2 of 2 Daily Drilling Report Geothermal Resource Group 0 Weii ID: AGP TG-2 Well Name: Hot Springs Well Field: Hot Springs Bay Va Sect: 32 Town:69S Rng: 112W County:Aleutians East State:AK Report No: 23 Report For 01-Aug-10 Operator: City of Akutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 623 Drilling Days: 23 actual/22 plan RKB Elevation: 4.00 County: Aleutians East Vertical Depth(ft): 623 Days On Location: 23 Last Casing: 3.5 at 604 Field: Hot Springs Bay Hole Made: 10 Spud Date: 16-Jul-10 Next Casing: 1.660 at 1,500 Working Interest: Drilling Hrs: 0.5 Average ROP: 20.0 Last BOP Test: 31-Jul-10 Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 4 Total: 18 Current Operations: Circ and cooled well.Mix and spotted 1 bbl of 13.5 lb cmt at @ 623'. POH t/343'and squeezed.CIP @ 02:30.WOC. Planned Operations: Clean out cement to 623'.Core 2.75"hole to 643'and conduct leakoff test. Drill ahead. Toolpusher: David Griggs. Wellsite Supervisors: Dan Darnell Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 0:30 0.50 613 OTHER Switch over to NQ, 0:30 4:30 4.00 613 TRPI Tripped in hole.Tagged and cleaned out cement stringer f/400't/581'.Tagged TOC @ 581'. 4:30 5:00 0.50 613 CMTD Cleaned out wiper plug and cement f/581't/583'. 5:00 8:00 3.00 613 TRPO POH due to cement stuck in core barrel.Ran in hole to 583' 8:00 8:30 0.50 613 BOPT Tested 3.5 HQ casing to 750 psi for 10 min.Test good. 8:30 9:30 1.00 613 CIRC Circ and conditioned hole @ 583'. 9:30 13:30 4.00 613 CMTD Cleaned out float collar @ 592'. Cleaned out cement and shoe to 603'. 13:30 15:00 1.50 613 CMTD Drilled cement to 613'. 15:00 17:30 2.50 613 TRPI POH for repairs.The upper latch body was unscrewed from lower latch assy,Ran in X hole to 613' 17:30 18:00 0.50 623 DRIL Core 2.98"hole f/613't/623'. X 18:00 19:30 1.50 623 FIT POH to shoe and conducted leak-off test using 8.4 ppg fluid. Leaked off at 50 psi and 7 gallons.Bled down to 20 psi.Fracture gradient =.52 psi/ft. 19:30 21:00 1.50 623 CIRC Circ bottoms up @ 623'. 21:00 22:00 1.00 623 OTHER Mixed and spotted 50 vis gel pill @ 623'. 22:00 0:00 2.00 623 FIT POH into shoe&waited 30 min.Conducted leak off test#2.Pumped 3 gallons and pressured up to 60 psi and stopped.Pumped 1 gallon and pressure spiked to 150 psi, bled off to 100 psi.Pumped 1 gallon and pressure spiked to 250 psi but bled down to 65 psi and held. Results inconclusive. Prepared to perform squeeze. ,.' Comments Cleaned out float and shoe and drilled ahead 20 feet. Performed leakoff test with resultant 0.52 gradient. Set gel pill on bottom and performed a second leakoff test-estimated gradient at 0.54 but pressure reading were difficult to interpret. Perpared to perform cement squeeze of shoe. Casing Information Type Size Top MD Top TVD Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.675 4 37 COND FULL 4.500 3 3 157 157 SURF 5.500 12.00 FULL 3.500 -3 604 3.870 Cost/AFE Information AFE No AFE Description AFE Amount Daily Mud Well Mud Daily Total Well Total %Spent No AFE Assigned 0 0 0 14,697 751,499 Totals$: 0 0 0 14,697 751,499 Mud Information _._.. . _ % Gels Temp Density Vis PV YP Filt. Cake pH Solids Oil Water Sand Chloride Calcium 10s 10m 30m In Out 01-Aug-10 08:00 804.00 32 7 0 75 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 6 1 FORDIF F6M 3.062 613 10 0.5 20.0 Jets: Out: 671 Grade: Cutter: / Dull: / Wear: Brgs: Gge: Pull: PR Printed: 19:50 13-Sep-10 RIMBase 5.1.1.177 Page: 1 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well Field: Hot Springs Bay Va Sect: 32 Town: 69S Rng: 112W County:Aleutians East State:AK Report No: 23 Report For 01-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 613 623 20.0 30.0 Comments: Core w/2.75 f/613'to 623' Rig Information Equipment Problems: Elastomers melted on inner barrel. Location Condition: muddy Transport: Safety Information Meetings/Drills Time Description Safety 30 Safety meeting held with both crews First Aid: Medical: Lost Time Accidents: Days Since LTA: 22 BOP Test ❑ Crownamatic Check Weather Information Sky Condition: Cloudy/Rain Visibility: 0.25 Air Temperature: 46.0 degF Bar.Pressure: Wind Speed/Dir: 25/N Wind Gusts: 45 Printed: 19:50 13-Sep-10 RIMBase 5.1.1.177 Page:2 of 2 Daily Drilling Report Geothermal Resource Group 0 Well ID: AGP TG-2 Well Name::Hot Springs Well Field: Hot Springs Bay Va Sect: 32 Town:69S Rng: 112W County:Aleutians East State:AK Report No: 24 Report For 02-Aug-10 Operator: City of Akutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 661 Drilling Days: 24 actual/22 plan RKB Elevation: 4.00 County: Aleutians East Vertical Depth(ft): 661 Days On Location: 24 Last Casing: 3.5 at 604 Field: Hot Springs Bay Hole Made: 38 Spud Date: 16-Jul-10 Next Casing: 1.660 at 1,500 Working Interest: Drilling Hrs: 5.5 Average ROP: 6.9 Last BOP Test: 31-Jul-10 Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 4 Total: 18 Current Operations: Core 2.98"hole f/661't/671',POH for bit.RIH.451'@ 06:00 hr's. Planned Operations: RIH. Run Pressure/Temperature survey and drill ahead. Toolpusher: David Griggs. Wellsite Supervisors: Dan Darnell Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 2:30 2.50 623 CMTPL Circ and cooled well @ 623',temp out= 109 deg F.Mixed 1 bbl of 13.51b cement and spotted @ 623'.POH to 363'and filled hole.Closed annular and squeezed. Squeezed a total of 25 gals of cement from inital pressure of 65 psi to a final pressure of 500 psi. Held for 15 min and bled off pressure.CIP @ 02:30. 2:30 10:30 8.00 623 WOC WOC 8 hours.Opened well and circulated core rods clean @ 363'. 10:30 11:00 0.50 623 TRPI RIH and tagged TOC @ 503'. 11:00 16:00 5.00 623 CMTD Cleaned out firm cement f/503'1/623'. 16:00 16:30 0.50 623 CIRC Circulated and cooled hole @ 623'. 16:30 18:00 1.50 643 DRIL Cored 2.98"hole f/623'1/643'. 18:00 18:30 0.50 643 EVAL Ran MRT at 640'. BHT=216 deg F 18:30 19:00 0.50 643 FIT Spotted 30 gal,50 vis gel pill @ 643'.POH to 553'and circ excess mud out of hole. Performed timed leak-off test with 8.4 ppg fluid in hole at a rate of 0.75 gal a min. Pressure broke over @ 180 psi.Fracture gradient =.74 psi/ft.' 19:00 20:00 1.00 643 WASH Circ&conditioned hole f/603'to 643'. 20:00 0:00 4.00 643 DRIL Cored 2.98"hole f/643'1/661' Comments Squeezed shoe with 25 gallons of cement. WOC. Cleaned out cement and drilled ahead to 643'. Performed timed leakoff test with 8.4 ppg mud to 180 psi surface pressure-gradient=.74 psi/ft. Cored f/643't/661'. Casing Information Type Size Top MD Top TVD Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.675 4 37 COND FULL 4.500 3 3 157 157 SURF 5.500 12.00 FULL 3.500 -3 604 3.870 Cost!AFE Information AFE No AFE Description AFE Amount Daily Mud Well Mud Daily Total Well Total %Spent No AFE Assigned 0 0 0 16,005 767,504 Totals$: 0 0 0 16,005 767,504 Mud Information Gels Temp Density Vis PV YP Filt. Cake pH Solids Oil Water Sand Chloride Calcium 10s 10m 30m In Out 02-Aug-10 22:00 8.40 32 7 0 72 110 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 FORDIF F6M 3.062 613 48 6 8.0 10.0 600 1200 8 598 596 Jets: Out: 671 Grade: Cutter: / Dull: / Wear: Brgs: Gge: Pull: PR 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 623 661 5.0 10.0 300 400 1100 1200 69 70 460 Annular Velocity: Drill Collars: 598.0 Drill Pipe: 629.0 Printed: 19:50 13-Sep-10 RIMBase 5.1.1.177 Page: 1 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well Field: Hot Springs Bay Va. Sect: 32 Town: 69S Rng: 112W County:Aleutians East State:AK Report No: 24 Report For 02-Aug-10 Miscellaneous Drilling Parameters Hook Loads(lbs): Off Bottom Rotate: Pick Up: Slack Off: Drag Avg/Max: / 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 623 661 Formation Name: Lithology: Rig Information Equipment Problems: Problems with light plant getting hot Location Condition: muddy Transport: Safety Information Meetings/Drills Time Description Safety 30 Safety meeting held with both crews First Aid: Medical: Lost Time Accidents: Days Since LTA: 23 ❑ BOP Test Crownamatic Check Weather Information Sky Condition: Rain Visibility: 0.25 Air Temperature: 47.0 degF Bar.Pressure: Wind Speed/Dir: 0/ Wind Gusts: Printed: 19:50 13-Sep-10 RIMBase 5.1.1.177 Page:2 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well Field: Hot Springs Bay Va Sect: 32 Town: 69S Rng: 112W County:Aleutians East State:AK Report No: 25 Report For 03-Aug-10 Operator: City of Akutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 713 Drilling Days: 25 actual/22 plan RKB Elevation: 4.00 County: Aleutians East Vertical Depth(ft): 713 Days On Location: 25 Last Casing: 3.5 at 604 Field: Hot Springs Bay Hole Made: 52 Spud Date: 16-Jul-10 Next Casing: 1.660 at 1,500 Working Interest: Drilling Hrs: 10.0 Average ROP: 5.2 Last BOP Test: 31-Jul-10 Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 4 Total: 18 Current Operations: Cored 2.98"hole f/713't/733'.Twisted off and left 30 of fish,inner barrel,and 700 ft of wire line in hole. Planned Operations: Attempt to recover fish in hole, Toolpusher: David Griggs. Wellsite Supervisors: Dan Darnell Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 2:30 2.50 671 DRIL Cored 2.98"hole f/661't/671'-full returns/no core recovery. 2:30 3:00 0.50 671 CIRC Circ @ 671'. X 3:00 3:30 0.50 671 OTHER Ran MRT,297 deg F. 3:30 5:30 2.00 671 TRPO Tripped for bit f/671'.Changed Bit#6. X 5:30 7:00 1.50 671 TRPI RIH in hole t/671',checked cellar for LEL. X 7:00 10:00 3.00 671 OTHER Rigged up and ran Pressure/Temperature survey to 658'. Max Temp(BHT)=300 deg F. 10:00 12:00 2.00 678 DRIL Cored 2.98"hole f/671'to 678'with full returns/no core recovery. Inner barrel stuck in X rods. 12:00 15:00 3.00 678 TRPO POH and recovered inner barrel. X 15:00 15:30 0.50 681 DRIL Cored 2.98"hole f/678 t/681'with full returns/no core recovery. Pulled tube and only X recovered the latch head. 15:30 17:00 1.50 681 TRPO POH to core barrel.Repaired inner barrel.Changed bit#7. X 17:00 18:30 1.50 681 TRPI Tripped in hole to 681'. X 18:30 19:00 0.50 681 CIRC Circ @ 681'.Checked cellar for LEL. X 19:00 0:00 5.00 713 DRIL Cored 2.98"hole f/681't/713'with full returns. Comments Cored f/661't/671'. Tripped for bit. Ran P/T survey to 658'. Cored f/671't/678'. POH to recover and repair inner core barrel. Cored f/678't/713'. Casing Information Type Size Top MD Top ND Bottom MD Bottom ND Hole Section Avg OH Diam LOT FULL 6.675 4 37 COND FULL 4.500 3 3 157 157 SURF 5.500 12.00 FULL 3.500 -3 604 3.870 Cost/AFE Information AFE No AFE Description AFE Amount Daily Mud Well Mud Daily Total Well Total %Spent No AFE Assigned 0 0 0 13,943 781,447 Totals$: 0 0 0 13,943 781,447 Mud Information Gels Temp Density Vis PV YP Filt. Cake pH Solids Oil Water Sand Chloride Calcium 10s 10m 30m In Out 03-Aug-10 21:00 8.40 37 0 80 115 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 FORDIF F6M 3.062 613 58 8.5 6.8 10.0 300 1200 8 70 596 Jets: Out: 671 Grade: Cutter: / Dull: / Wear: Brgs: Gge: Pull: PR 7 1 FORDIF F6M 3.062 671 10 2.5 4.0 5.0 300 1200 8 35 460 Jets: Out: 681 Grade: Cutter: / Dull: / Wear: Brgs: Gge: Pull: 8 1 FORDIF F6M 3.032 681 42 5 8.4 10.0 300 1200 8 35 305 Jets: Out: 733 Grade: Cutter: / Dull: / Wear: Brgs: Gge: Pull: Printed: 19:50 13-Sep-10 RIMBase 5.1.1.177 Page: 1 of 2 Daily Drilling Report Geothermal Resource Group Rid Well ID: AGP TG-2 Well Name: Hot Springs Well ' Field: Hot Springs Bay V2 Sect: 32 Town: 69S Rng: 112W County:Aleutians East State:AK Report No: 25 Report For 03-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 671 713 6.0 10.0 200 250 1100 1200 35 35 305 Comments: Cored 2.98"hole f/678'to 713' 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 661 713 Formation Name: Lithology: Rig Information Equipment Problems: Light plant Location Condition: muddy Transport: Safety Information Meetings/Drills Time Description Safety 30 Safety meeting held with both crews First Aid: Medical: Lost Time Accidents: Days Since LTA: 24 ill BOP Test j Crownamatic Check Weather Information Sky Condition: Rain Visibility: Air Temperature: 47.0 degF Bar.Pressure: Wind Speed/Dir: / Wind Gusts: Printed. 19:50 13-Sep-10 RIMBase 5.1.1.177 Page:2 of 2 Daily Drilling Report Geothermal Resource Group hcb0 Well ID: AGP TG-2 Well Name: Hot Springs Well Field: Hot Springs Bay Va Sect: 32 Town: 69S Rng: 112W County:Aleutians East State:AK Report No: 26 Report For 04-Aug-10 Operator: City of Akutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 793 Drilling Days: 26 actual/22 plan RKB Elevation: 4.00 County: Aleutians East Vertical Depth(ft): 793 Days On Location: 26 Last Casing: 3.5 at 604 Field: Hot Springs Bay Hole Made: 80 Spud Date: 16-Jul-10 Next Casing: 1.660 at 1,500 Working Interest: Drilling Hrs: 11.5 Average ROP: 7.0 Last BOP Test: 31-Jul-10 Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 4 Total: 18 Current Operations: Cored NQ hole f/793'U833'with 2-3 bph mud loss. POH due to stuck barrel. Planned Operations: Retrieve inner core barrel that is stuck. Toolpusher: David Griggs. Wellsite Supervisors: Dan Darnell Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 4:00 4.00 733 DRIL Cored 2.98"hole f/713't/733'with full returns and full recovery. 4:00 5:30 1.50 733 FISH Inner barrel was dropped and became stuck while retrieving.Attempted to retrieve tube X using wireline overshot-no success. 5:30 8:00 2.50 733 FISH Cut and released wire line and pulled out of hole with NQ rod. Core rod had twisted off X at 703'. Fish in hole comprised of inner core tube,over shot and latch assembly,700' of wire line with the outer core barrel attached and 30'of core rod. Estimated TOF @ 690'. 8:00 15:00 7.00 733 FISH Fabricated wireline spear and RIH. Tagged wire line @ 92'.Worked spear in line and X pulled out of hole.Cut and recovered wire line,latch assembly and inner core tube. Made up 2-1/2"tubing spear and RIH. Tagged top of fish @ 690'. Worked spear into top of fish& POH with fish.Made up 3.032"New Bit#8 and RIH t1733'. 15:00 16:00 1.00 733 SURV Ran wire line survey @ 710'with MRT.Survey=3/4 deg. BHT=320 deg F 16:00 16:30 0.50 733 OTHER Made up P/T tool and ran in hole to bottom. Result=300 psi BHP and 320.3 deg F BHT. 16:30 0:00 7.50 793 DRIL Cored 3.032"hole f/733't/793'.Began losing 2 to 3 bbls/hr @ 746'. Comments Cored NQ hole f/713'U733'. Dropped inner barrel and twisted off. Retrieved fish with wireline spear and taper tap. Ran in hole with new bit and performed temperature evaluation. Cored NQ hole f/733'U793'. Casing Information Type Size Top MD Top TVD Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.675 4 37 COND FULL 4.500 3 3 157 157 SURF 5.500 12.00 FULL 3.500 -3 604 3.870 Cost/AFE Information AFE No AFE Description AFE Amount Daily Mud Well Mud Daily Total Well Total %Spent No AFE Assigned 0 0 0 16,380 797,827 Totals$: 0 0 0 16,380 797,827 Mud Information Gels Temp Density Vis PV YP Filt. Cake pH Solids Oil Water Sand Chloride Calcium 10s 10m 30m In Out 04-Aug-10 22:00 8.40 38 75 90 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 8 1 FORDIF F6M 3.032 681 42 9 4.7 5.0 300 1200 8 35 275 Jets: Out: 733 Grade: Cutter: / Dull: / Wear: Brgs: Gge: Pull: 9 1 ADT 2A0 3.032 733 60 7.5 8.0 15.0 300 1200 8 35 285 Jets: Out: Grade: Cutter: / Dull: / Wear: Brgs: Gge: Pull: Printed: 19:50 13-Sep-10 RIMBase 5.1.1.177 Page: 1 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well Field: Hot Springs Bay Va Sect: 32 Town: 69S Rng: 112W County:Aleutians East State:AK Report No: 26 Report For 04-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 713 793 10.0 20.0 300 400 1100 1200 35 70 285 Comments: Cored 3.032"hole f/713'to 793'losing around 2 to3 bbls an hr Survey Information Survey Meas. Vertical Coordinates Type Depth Inc. Azimuth TVD Closure Section N-S E-W D.L.S. TOTCO 710.0 0.75 TOTCO 803.0 1.25 Rig Information Equipment Problems: Light plant Location Condition: muddy Transport: Safety Information Meetings/Drills Time Description Safety 30 Safety meeting held with both crews First Aid: Medical: Lost Time Accidents: Days Since LTA: 25 ❑ BOP Test ❑ Crownamatic Check Weather Information Sky Condition: Rain Visibility: 2.5 Air Temperature: 44.0 degF Bar.Pressure: Wind Speed/Dir: / Wind Gusts: Printed. 19:50 13-Sep-10 RIMBase 5.1.1.177 Page:2 of 2 Daily Drilling Report Geothermal Resource Group 1:14eb0 Well ID: AGP TG-2 Well Name: Hot Springs Well Field: Hot Springs Bay Va Sect: 32 Town:69S Rng: 112W County:Aleutians East State:AK Report No: 27 Report For 05-Aug-10 Operator: City of Akutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 833 Drilling Days: 27 actual/22 plan RKB Elevation: 4.00 County: Aleutians East Vertical Depth(ft): 833 Days On Location: 27 Last Casing: 3.5 at 604 Field: Hot Springs Bay Hole Made: 40 Spud Date: 16-Jul-10 Next Casing: 1.660 at 1,500 Working Interest: Drilling Hrs: 4.0 Average ROP: 10.0 Last BOP Test: 31-Jul-10 Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 4 Total: 18 Current Operations: Continued to let well stand the first 12 hr pressure and temperature log.Made up PT tools and began logging entire well bore.Well began flowing near end of first test.Mixe CaCI brine to 9.5 ppg. Killed well and displaced well bore @ 06:00 hr's. Planned Operations: Finish displacing well with 9.5#brine and resume logging. Toolpusher: David Griggs. Wellsite Supervisors: Dan Darnell Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 4:00 4.00 833 DRIL Cored 3.032"hole f/793't/833'.Lost 2-3 bbl/hr. 4:00 5:30 1.50 833 TRPO Unable to retrieve inner barrel.POH-left core barrel and 10'of NQ in hole. X 5:30 12:00 6.50 833 FISH Made up 2.50"spear and RIH.Tagged top of fish @ 810'.Worked spear into top of fish X and POH.Layed out fish and inspected tools and equipment. RR bit#9 and RIH to 833'. 12:00 13:30 1.50 833 CIRC Circ and cooled well. Mixed and displaced well bore with 9.1 #CaCI brine.Stopped circulating @ 13:30 hrs. 13:30 0:00 10.50 833 TEST Waiting on well to heat up for 12 hrs prior to pressure and temperature logging. Comments Cored NQ hole f/793't1833'w/2-3 bph loss. Twisted off and left 23'fish in hole. RIH&retrieved fish. Circulated and conditioned wellbore for logging to 9.1#with CaCI brine. Waited on well to heat up before logging. Casing Information Type Size Top MD Top TVD Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.675 4 37 COND FULL 4.500 3 3 157 157 SURF 5.500 12.00 FULL 3.500 -3 604 3.870 Cost/AFE Information AFE No AFE Description AFE Amount Daily Mud Well Mud Daily Total Well Total %Spent No AFE Assigned 0 0 0 10,155 807,982 Totals$: 0 0 0 10,155 807,982 Mud Information % Gels Temp Density Vis PV YP Filt. Cake pH Solids Oil Water Sand Chloride Calcium 10s 10m 30m In Out 05-Aug-10 22:00 8.40 36 75 90 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 9 1 ADT 2A0 3.032 733 100 11.5 8.7 15.0 300 1200 8 35 325 Jets: Out: 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 793 833 5.0 10.0 300 400 1100 1200 35 70 325 Comments: Cored 3.032"hole f/793'to 833'.losing 2 to 3 bbl an hr, Rig Information Equipment Problems: Light plant Location Condition: muddy Transport: Printed: 19:50 13-Sep-10 RIMBase 5.1.1.177 Page: 1 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well Field: Hot Springs Bay V2 Sect: 32 Town: 69S Rng: 112W County:Aleutians East State:AK Report No: 27 Report For 05-Aug-10 Safety Information Meetings/Drills Time Description Safety 30 Safety meeting held with both crews First Aid: Medical: Lost Time Accidents: Days Since LTA: 26 ❑ BOP Test Crownamatic Check Weather Information Sky Condition: Clear/cloudy Visibility: Air Temperature: Bar.Pressure: Wind Speed/Dir: / Wind Gusts: Printed: 19:50 13-Sep-10 R/MBase 5.1.1.177 Page:2 of 2 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well Field: Hot Springs Bay Va Sect: 32 Town: 69S Rng: 112W County:Aleutians East State:AK Report No: 28 Report For 06-Aug-10 Operator: City of Akutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 833 Drilling Days: 28 actual/22 plan RKB Elevation: 4.00 County: Aleutians East Vertical Depth(ft): 833 Days On Location: 28 Last Casing: 3.5 at 604 Field: Hot Springs Bay Hole Made: 0 Spud Date: 16-Jul-10 Next Casing: 1.660 at 1,500 Working Interest: Drilling Hrs: 0 Average ROP: 0 Last BOP Test: 31-Jul-10 Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 4 Total: 18 Current Operations: Continued Temperature/Pressure buildup. Planned Operations: Continue Temperature/Pressure buildup for next log run at 07:45 hrs. Follow on with third log run. Toolpusher: David Griggs. Wellsite Supervisors: Dan Darnell Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 1:30 1.50 833 TEST Let well heat up for down hole temperature survey's 1:30 5:30 4.00 833 TEST Opened well&began Pressure/Temperature logging.Initial stop at 50'and 100', followed by 20'stops to TD. 5:30 7:45 2.25 833 TEST Well began flowing.Mixed and displaced well bore with 9.5#Cala brine.Circulated 14 minutes. Last circ time @ 07:44 hrs. 7:45 19:45 12.00 833 TEST Allow 12 hour Temperature/Pressure buildup. 19:45 23:45 4.00 833 TEST Ran Pressure/Temperature log as per previous test. 23:45 0:00 0.25 833 TEST Allow Temperature/Pressure buildup. Comments Allowed P/T buildup and began logging. Well flowed at last stop. Killed well with 9.6#brine and pulled tool. Waited on buildup prior to running P/T log. Ran PIT logs. Waited on buildup for next test. Casing Information Type Size Top MD Top ND Bottom MD Bottom TVD Hole Section Avg OH Diam LOT FULL 6.675 4 37 COND FULL 4.500 3 3 157 157 SURF 5.500 12.00 FULL 3.500 -3 604 3.870 Cost/AFE Information AFE No AFE Description AFE Amount Daily Mud Well Mud Daily Total Well Total %Spent No AFE Assigned 0 0 0 13,905 821,887 Totals$: 0 0 0 13,905 821,887 Mud Information % Gels Temp Density Vis PV YP Filt. Cake pH Solids Oil Water Sand Chloride Calcium 10s 10m 30m In Out 06-Aug-10 22:00 9.60 27 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 833 833 Comments: Mixed mud to 9.5#Cal Cloride brine and displace well bore Rig Information Equipment Problems: Light plant Location Condition: muddy Transport: Safety Information Meetings/Drills Time Description Safety 30 Safety meeting held with both crews First Aid: Medical: Lost Time Accidents: Days Since LTA: 27 ❑ BOP Test ❑ Crownamatic Check Printed: 19:50 13-Sep-10 RIMBase 5.1.1.177 Page: 1 of 1 www... Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well Field: Hot Springs Bay V2 Sect:32 Town:69S Rng: 112W County:Aleutians East State:AK Report No: 29 Report For 07-Aug-10 Operator: City of Akutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 833 Drilling Days: 29 actual/22 plan RKB Elevation: 4.00 County: Aleutians East Vertical Depth(ft): 833 Days On Location: 29 Last Casing: 3.5 at 604 Field: Hot Springs Bay Hole Made: 0 Spud Date: 16-Jul-10 Next Casing: 1.660 at 1,500 Working Interest: Drilling Hrs: 0 Average ROP: 0 Last BOP Test: 31-Jul-10 Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 4 Total: 18 Current Operations: POH to shoe @ 603'. Flowed well. Planned Operations: Kill well&lay out NQ rod. Run 1.66"tubing and hang @ surface. Nipple down and begin demobilizing. Toolpusher: David Griggs. Wellsite Supervisors: Dan Darnell Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 7:30 7.50 833 TEST Allowed temperature buildup for logs. 7:30 11:30 4.00 833 TEST Ran Pressure/Temperature logs-20'stops f/100'to TD.BHT=328 deg F 11:30 17:30 6.00 833 TEST Allowed temperature buildup for logs. 17:30 0:00 6.50 833 TEST Ran Pressure/Temperature logs-20'stops from 100'to TD. BHT`-330 deg F. - Comments Performed Pressure/Temperature logs at the 24 hour and 36 hour mark. Casing Information Type Size Top MD Top ND Bottom MD Bottom ND Hole Section Avg OH Diam LOT FULL 6.675 4 37 COND FULL 4.500 3 3 157 157 SURF 5.500 12.00 FULL 3.500 -3 604 3.870 Cost/AFE Information AFE No AFE Description AFE Amount Daily Mud Well Mud Daily Total Well Total %Spent No AFE Assigned 0 0 0 13,905 835,792 Totals$: 0 0 0 13,905 835,792 Mud Information % Gels Temp Density Vis PV YP Filt. Cake pH Solids Oil Water Sand Chloride Calcium 10s 10m 30m In Out 07-Aug-10 22:00 9.50 65 113 Rig Information Equipment Problems: Light plant Location Condition: muddy Transport: Safety Information Meetings/Drills Time Description Safety 30 Safety meeting held with both crews First Aid: Medical: Lost Time Accidents: Days Since LTA: 28 ❑ BOP Test ❑ Crownamatic Check Weather Information Sky Condition: cloudy Visibility: Air Temperature: Bar.Pressure: Wind Speed/Dir: / Wind Gusts: 75 Printed: 19:50 13-Sep-10 RIMBase 5.1.1.177 Page: 1 of 1 Daily Drilling Report Geothermal Resource Group Well ID: AGP TG-2 Well Name: Hot Springs Well Field: Hot Springs Bay Va Sect: 32 Town: 69S Rng: 112W County:Aleutians East State:AK Report No: 30 Report For 08-Aug-10 Operator: City of Akutan Rig: Major LF90 Proposed TD: 1,500 State: AK Measured Depth(ft): 833 Drilling Days: 30 actual/22 plan RKB Elevation: 4.00 County: Aleutians East Vertical Depth(ft): 833 Days On Location: 30 Last Casing: 1.66 at 818 Field: Hot Springs Bay Hole Made: 0 Spud Date: 16-Jul-10 Next Casing: Working Interest: Drilling Hrs: 0 Average ROP: 0 Last BOP Test: 31-Jul-10 Personnel: Operator: 3 Contractor: 7 Service: 4 Other: 4 Total: 18 Current Operations: Waiting on daylight.Final Report. Planned Operations: Load out and move rig. Toolpusher: David Griggs. Wellsite Supervisors: Dan Darnell Tel No.: Operations Summary From To Elapsed End MD(ft) Code Operations Description Non-Prod 0:00 11:00 11.00 833 TEST Pulled NQ rod to shoe and allowed well to flow. Well flowed at aproximately 6 bph with max temperature of 216 deg F on blooie line. 11:00 15:00 4.00 833 CIRC Killed well w/cold water. 15:00 15:30 0.50 833 TRPI RIH U 833'. 15:30 16:00 0.50 833 CIRC Mixed and displaced 9.6#CaCI brine throughout wellbore @ 833'. 16:00 18:00 2.00 833 TRPO POH and layed out NQ 2.75"rods. 18:00 19:00 1.00 833 OTHER Picked up and loaded V-Door w/1-1/4"tubing. 19:00 21:00 2.00 833 CASE Made up 1-1/4"check valve on 1.66"tubing.Ran 39 joints/819'of 1.66"tubing and. hung off bottom. Nippled down BOP and installed and tightened well head flange. Installed 1-1/4"tubing valve. Comments Allowed well to flow. Killed well and layed down core rod. Made up 1.66"tubing and ran to 818'. Hung off bottom and nippled down BOPE. Well secured with valve in place. Casing Information Type Size Top MD Top TVD Bottom MD Bottom ND Hole Section Avg OH Diam LOT FULL 6.675 4 37 GOND FULL 4.500 3 3 157 157 SURF 5.500 12.00 FULL 3.500 -3 604 3.870 HNG DN 1.660 -1 818 OPEN 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 0 265,460 1,101,252 Totals$: 0 0 0 265,460 1,101,252 Rig Information Equipment Problems: Light plant Location Condition: muddy Transport: Safety Information Meetings/Drills Time Description Safety 30 Safety meeting held with both crews First Aid: Medical: Lost Time Accidents: Days Since LTA: 29 0 BOP Test 0 Crownamatic Check Weather Information Sky Condition: Partly Cloudy/Rain Visibility: Air Temperature: Bar.Pressure: Wind Speed/Dir: / Wind Gusts: 25 Printed: 19:50 13-Sep-10 RIMBase 5.1.1.177 Page:1 of 1 Directional Survey Report Geothermal Resource Group Well ID: AGP TG 2 Well Name: Hot Springs Well Field: Hot Springs Bay Va Sect: 32 Town: 69S Rng: 112W County:Aleutians East State: AK 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 TOTCC 100.0 0.00 0 100.0 0.0 0.0 0.0 0.0 0.000 TOTCC 157.0 0.75 TOTCC 241.0 2.25 TOTCC 370.0 1.75 TOTCC 469.0 2.25 TOTCC 553.0 3.75 TOTCC 710.0 0.75 TOTCC 803.0 1.25 Calculations using Minimum Curvature Method Printed: 19:52 13-Sep-10 RIMBase 5.1.1.177 Page: 1 of 1 Page 1 of 3 Regg, James B (DOA) From: Alan Bailey [alanbailey@geothermalresourcegroup.com] Sent: Wednesday, August 04, 2010 2:32 PM 2,141 10 To: Regg, James B (DOA) �q Cc: Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay; Aubert, Winton G (DOA) Subject: RE: AOGCC BOP Worksheet Jim, (9,10 I checked again and it is a 1"valve, not a 1-1/4"valve. Should I resubmit the worksheets? From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Wednesday, August 04, 2010 3:29 PM To: Alan Bailey Cc: Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay; Aubert, Winton G (DOA) Subject: RE: AOGCC BOP Worksheet Thank you for addressing my questions. AOGCC only requires the stable pressure to be held for 5 min For future reports, please show test pressures as LP/HP -e.g., 200/750 Attached is BOPE schematic we were provided with permit showing kill line valve as 1"; report indicates this is 1-1/4"; could you confirm which is correct? Attached are corrected reports for 7/22/10 and 7/31/10 -7/22/10: 2 failures noted by Inspector(3" gate valve; accumulator regulator valve) -7/31/10: report indicates 3 failures (Annular; HCR; BOP Misc all shown as FP but"Number of Failures" = 2) Finally, attached is updated BOPE test template that includes Contractor and Rig name for your ops at Akutan. 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 04, 2010 8:27 AM To: Regg, James B (DOA) Cc: Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay; Aubert, Winton G (DOA) Subject: RE: AOGCC BOP Worksheet James, I have attached the worksheets for the first and second BOP tests. The first test was witness by Jeff Jones. The contractor is NANA Major Drilling and the rig is LF90. The low pressure tests were 200 psi and high pressure were 750 psi. We'll be sure to concentrate on getting the 10 minute baseline at 750 psi rather than the 30 minute/10 percent bleed-off on the next test—we're accustomed to doing it that way in NV, CA and on BLM land, but we need to conform to AOGCC standard. A couple of the items on /A/1(11 n Page 2 of 3 the form I sent you previously were mismarked. 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 X Untitled From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, August 03, 2010 10:45 AM To: Alan Bailey Cc: Brooks, Phoebe L(DOA); DOA AOGCC Prudhoe Bay; Aubert, Winton G (DOA) Subject: RE: AOGCC BOP Worksheet Akutan Hot Springs Bay #2 (PTD 2100710) BOPE Test Reports - Please also submit BOPE test report for 7/22/10 (initial test, witnessed by Jeff Jones) -7/31/10 is weekly test, not initial (not sure what DD means here) -Contractor= GRG? - Rig = LF90? - Low pressure test= 200psi? - Reviewing BOPE test chart that you also provided, I don't see the 750 psi pressure referred to in test report; must be stable (flat line) at 750 psi for 5 minutes to be valid 750 psi test pressure -this is Commission standard for all BOPE tests and API RP 53 criteria for BOPE equipment; it appears you are attempting to apply casing pressure test criteria which typically allows for up to 10% loss during a 30 minute test if pressure is trending toward stabilization -Time to reach 200 psi (200 sec) can't be longer than time to reach full pressure (18 sec) -What is the misc Accumulator component marked as 1 and N/A? - In your initial report(7/22/10) please document in remarks the independent power source(s) available for closing BOPE that were tested. This is important since you were allowed this past weekend to continue with cementing ops while relying on nitrogen backup system (failed diesel engine (pirmary power for accumulator)) because of the testing done with nitrogen Jim Regg AOGCC 333 W.7th Avenue,Suite 100 Anchorage,AK 99501 907-793-1236 8/4/2010 Page 3 of 3 From: Alan Bailey [mailto:alanbailey@geothermalresourcegroup.com] Sent: Monday, August 02, 2010 4:18 PM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Cc: Jones, Jeffery B (DOA); Aubert, Winton G (DOA); 'Amanda Kolker'; 'dan darnell'; 'Randy Baldwin'; 'Ray Mann'; dougmiller@rmabs.com; billrickard@geothermalresourcegroup.com Subject: AOGCC BOP Worksheet I have attached the worksheet and a copy of the test results. I hope I have completed this correctly. We are currently drilling out in preparation to test the shoe after squeezing this morning. Thanks and regards 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 X! Untitled 8/4/2010 Akutan Test Wells Cellar Configuration Drawn by A.Bailey,GRGI 5/25/2010-Not To Scale Rig Floor > ,, CV CO - co 6-5/8" x 14" riser > 2 0 0 7-1/16 3M --/ 0° N. Annular Preventer jf, co N I l r co Co 1 v > N I _ 4 6" 900 Exp. Gate > 1 i c\ 0-. K Valve w/GT Trim m I lv T - - — l CD C\I x X N _ 4=,00 j v w •TCo GI -10 SI) w CDCD I Cellar - 72" Diameter STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: iim.reggna.alaska.qov d oa.aog cc.p rud hoe.bavCa.alas ka.qov phoebe.brooks( alaska.gov Contractor: NANA Major Drilling Rig No.: LF90 DATE: 7/22/10 Rig Rep.: David Griggs Rig Phone: 907-444-1777 Rig Fax: Operator: City of Akutan Op. Phone: 907-444-1777 Op. Fax: Rep.: Randy Baldwin E-Mail randybaldwin54@yahoo.com Well Name: Hot Springs Bay#2 PTD# 2100710 Operation: DrIg: x Workover: Explor.: x 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 0 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 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 60 P No. Valves 0 NA Full Pressure Attained 120 P Manual Chokes 0 NA Blind Switch Covers: All stations NO Hydraulic Chokes 0 NA Nitgn. Bottles (avg): 2500 CH Misc 0 NA ACC Misc 1 FP Test Results Number of Failures: 2 Test Time: 4.0 Hours Repair or replacement of equipment will be made within 1 days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Supervisor at: 'im.reg_• • alaska.gov Remarks: Tested master valve, pneumatic valve, diverter valve, and kill line to 750 psi. Approx 35 degree loss after 10 minutes. Ran test plug and tested annular preventer to 750 psi. Tested accumulator and LEL alarms; regulator valve required sporadic adjustment; replaced, passed retest. Tests approved as per 24 HOUR NOTICE GIVEN YES X NO Waived By Date 7/20/10 Time 07:30 Witness Jeff Jones Test start 14:30 Finish 18:30 Form 10-424 (Revised 06/2010) BOP NANA LF90 07-22-10 (2).xls • • STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: jim.regcaalaska.gov doa.aogcc.Drudhoe.bay@alaska.gov phoebe.brooks(a�alaska.qov Contractor: NANA Major Drilling Rig No.: LF90 DATE: 7/31/10 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: Hot Springs Bay#2 PTD# 2100710 Operation: DrIg: x Workover: Explor.: x 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 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 FP 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 0 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 FP Kill Line Valves 1 1 P Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 1 3 1/8 3M FP Time/Pressure Test Result System Pressure 3000 P CHOKE MANIFOLD: Pressure After Closure 2800 P Quantity Test Result 200 psi Attained 60 P No. Valves 0 NA Full Pressure Attained 120 P Manual Chokes 0 NA Blind Switch Covers: All stations NO Hydraulic Chokes 0 NA Nitgn. Bottles (avg): 2200 CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures: 2 Test Time: 2.3 Hours Repair or replacement of equipment will be made within 2 days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Supervisor at: jim.regq@alaska.gov Remarks: Rig broke down for 3 days after giving 24 hr notice, Ran and cemented 603 ft. of 3 1/2 inch casing on 7/29/10. WOC. Tested BOP-small surface leak that could not be detected. Tore down BOPE and replaced all API rings. All equipment tested afterward. Accumulator operated using nitrogen-6 24 HOUR NOTICE GIVEN YES X NO Waived By Jeff Jones Date 7/30/10 Time 10:00 Witness Test start 18:05 Finish 23:22 Form 10-424 (Revised 06/2010) BOP NANA LF90 07-31-10 (3).xls STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: jim.regq(a alaska.gov doa.aogcc.prud hoe.bav(a�alaska.gov phoebe.brooks analaska.gov Contractor: Contractors Rig No.: Rig#'s DATE: Rig Rep.: Rig Phone: Rig Fax: Operator: Op. Phone: Op. Fax: Rep.: E-Mail Well Name: PTD# Operation: Drlg: Workover: Explor.: Test: Initial: Weekly: Bi-Weekly Test Pressure: Rams: Annular: Valves: MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: I Well Sign I Upper Kelly I I Housekeeping: I Drl. Rig I Lower Kelly I I PTD On Location I Hazard Sec. I Ball Type I I Standing Order Posted I Misc I Inside BOP I I FSV Misc I I BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper I I Trip Tank I I Annular Preventer I I Pit Level Indicators I I #1 Rams I I Flow Indicator I I #2 Rams I I Meth Gas Detector I I #3 Rams I I H2S Gas Detector I I #4 Rams I I MS Misc I I #5 Rams I I #6 Rams I I Quantity Test Result Choke Ln. Valves I I Inside Reel valves I I HCR Valves I I Kill Line Valves I I Check Valve I I ACCUMULATOR SYSTEM: BOP Misc I I Time/Pressure Test Result System Pressure I CHOKE MANIFOLD: Pressure After Closure I Quantity Test Result 200 psi Attained I No. Valves I I Full Pressure Attained I Manual Chokes I I Blind Switch Covers: All stations I Hydraulic Chokes I I Nitgn. Bottles (avg): CH Misc I I ACC Misc I I Test Results Number of Failures: Test Time: Hours Repair or replacement of equipment will be made within days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Supervisor at: jim.regq@alaska.gov Remarks: 24 HOUR NOTICE GIVEN YES NO Waived By Date Time Witness Test start Finish Cr,rrri 1!1_A 7A /Rcsriccrl fl P)(11l1\ PCDG Gnrm /1R_!l1_on 1/1 /Al vie Davies, Stephen F (DOA) From: Aubert, Winton G (DOA) Sent: Wednesday, June 23, 2010 6:59 AM To: Seamount, Dan T(DOA); Foerster, Catherine P (DOA); Davies, Stephen F (DOA) Subject: FW: City of Akutan Geothermal Project - Permitting FYI. I think Akutan's permit is ready for approval. Thanks, WGA From: Robert IGrkman [mailto:REKirkman@rmabs.com] Sent:Tue 6/22/2010 6:44 PM To: Aubert, Winton G (DOA) Cc: 'Alan Bailey'; 'Ray Mann' Subject: City of Akutan Geothermal Project- Permitting Winton, The City has reached an agreement on the Designated Operator form, and has made initial contact with the Permit Inspectors Office to initiate arrangements for an inspector to be present during rig-up. It's our understanding that permit requirements will need to be in-place before this site visit can be actually scheduled. I know that you and our Drilling Manager-Alan Baily are continuing to discuss technical requirements specific to H2S monitoring, and methane detection. At this juncture we would like your input regarding any additional actions required from our end to finalize the permit process and issuance. Regards, 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 1 Davies, Stephen F (DOA) From: Davies, Stephen F(DOA) Sent: Friday, June 18, 2010 11:42 AM To: 'REKirkman©rmabs.com' Cc: Aubert, Winton G (DOA) Subject: Designation of Operator Form Received on 6/18/10 Attachments: Designation of Operator Signed.pdf Mr. Kirkman, I'm Steve Davies,a petroleum geologist at the Alaska Oil and Gas Conservation Commission,and I am responsible for reviewing a portion of every permit to drill application along with all associated administrative documents,such as the Designation of Operator form submitted on 6/18/10(attached). This particular form is a standard Commission form that is used every time the current owner of a property(owner of the subsurface rights)wishes to designate a separate party as operator for that property(the party being given the right to drill and produce). The purpose of the form is to be a simple statement in which the current owner clearly designates the separate entity as the operator for the property,and the newly-designated operator clearly accepts all responsibilities and obligations for all operations conducted on the property. The Commission requires Powers of Attorney,or equivalent documents,that specify each of the persons signing the form have the legal authority to bind their respective corporations to lease agreements. My understanding is that the current owner of record of the subsurface rights for this particular property is the Aleut Corporation and that the Aleut Corporation is designating City of Akutan as the operator for this geothermal exploratory drilling program. Mr. Bereskin,as Mayor of the City of Akutan,can sign the form as the newly-designated operator of the property, but Mr. Bereskin cannot also sign the form for the owner(Aleut Corporation),unless he is also a legal representative for the Aleut Corporation. So,the Designation of Operator form must be redone showing the current owner of record as the Aleut Corporation and the City of Akutan as the designated operator,with Mr. Bereskin signing as legal representative for the City of Akutan and an authorized legal representative of Aleut Corporation signing as owner. If you have any questions,please call me at 907-793-1224. Thank you, Steve Davies Sr. Petroleum Geologist Alaska Oil and Gas Conservation Commission 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION DESIGNATION OF OPERATOR 20 AAC 25.020 1.Name and Address of Current Owner of Record: City of Akutan 3380 C Street,Suite 205 Anchorage,Alaska 99503-3952 - 2.Notice is hereby given of a designation of operatorship for the oil and gas property described below: Legal description of property: Meridian Township Range Section Seward 70S 112W 5-7 69S 112W 32&33 70S 113W 1&12 Surface/Subsurface Agreements Attached Project Area Map Attached: Section Map Attached: El 3. Name and Address of Designated Operator: City of Akutan;3380 C Street Suite 205,Anchorage,AK 99503-3952 4. Effective Date of Designation: 24-Mar-09 5. Acceptance of operatorship for the above described property with all attendant responsibilities and obligations is hereby acknowledged (attach Power of Attorney or other evidence of authority of person signing): Signature Date 6 /7/O Printed Name Joseph Bereskin Title Mayor-City of Akutan 6. The Owner hereby certifies that the foregoing is true and correct(attach Power of Attorney or other evidence of authority of person signing): Signature �/% Date fl —/7`"f(! Printed Name Jose oh Bereskin Title Mayor-City of Akutan 7. Approved: Commissioner Date Approved: Commissioner Date Approved: Commissioner Date (Requires approval by two Commissioners) Form 10-411 Rev.7/2009 Submit in duplicate i c- O. 7 Z ZO J .A W b N (A W .w v' 41. CA..1x �Y 8 t tc en / ... ) . 0 y ce f ! W t 1 r+ O M �` _.. 1 z IC -_-_.i II 1.7 � M 2 ..+ 0 e , � I ! I} _` M _ r 7 Lin l 1 N 0 . _ •tel • N ! I Z Ai# -, 7 ;O — ,— a �'P. ^vi A ��� tN 40 LU �N'4 CC CC Lu N .... 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Jun 09 09 02:51p City of Akutar 91 8-2202 p3 CITY OF AKUTAN P.O.Box 109 Akutan,Alaska 99553 AKUTAN Phone(907)698-2228 Fax(907)698-2202 4 CITY OF AKUTAN,ALASKA RESOLUTION NO.09-08 A RESOLUTION OF THE AKUTAN CITY COUNCIL AUTHORIZING THE MAY•R OF AKUTAN TO EXECUTE A SUBSURFACE RESOURCES EXPLORATI I N AGREEMENT BETWEEN THE ALEUT CORPORATION ANI) THE CITY I F AKUTAN. WHEREAS, the City of Akutan is proceeding with a geothermal resource development proj• t on Akutan Island; and WHEREAS, the Aleut Corporation is the owner of certain subsurface rights on Akutan 1s1. d within the geothermal resource development project site; and WHEREAS, the City of Akutan and the Aleut Corporation have negotiated a mutu• ly acceptable Subsurface Resources Exploration Agreement for a reconnaissance and explorati•n of the geothermal resource development site; NOW, THEREFORE, BE IT RESOLVED BY THE CITY COUNCIL OF THE CITY t F AKUTAN,ALASKA: Section 1. The Mayor of Akutan is authorized to execute the "Subsurface Resources Agreem;nt Between the Aleut Corporation and The City of Akutan" for purposes of the reconnaissance . d exploration of geothermal resources on Akutan Island. Section 2. Effective Date. This Resolution shall become effective immediately upon adoptio . PASSED this 9th day of June 2009,by a vote of 6 in favor and 0 opposed. •e Bereskin, Mayor ATTEST: Amanda Tcheripanoff, City Clerk CITY OF AKUTAN, ALASKA RESOLUTION NO 09 08 AR 09-08 Subsurface doc Page 1 if l Subsurface Resources Exploration Agreement Between The Aleut Corporation And The City of Akutan WHEREAS, The Aleut Corporation ("Aleut") is the owner of certain subsurface rights on Akutan Island; and WHEREAS, the City of Akutan ('City") has executed a Surface Rights and Exploration Agreement with Akutan Corporation for purposes of a reconnaissance and exploration of geothermal resources on Akutan Island; and WHEREAS, the reconnaissance and exploration requires use of the subsurface estate owned by Aleut; and WHEREAS, Aleut supports City's efforts to develop geothermal resources on Akutan Island; NOW THEREFORE, in consideration of this Agreement and the mutual promises contained herein, Aleut and City agree as follows: 1. Term of this Agreement. The term of this Subsurface Resources Exploration Agreement ("Subsurface Agreement") shall be three (3) years from June 1, 2009 to May 30, 2012, unless sooner terminated pursuant to Section 7 of this Agreement. 2. Payment. For the rights granted under this Agreement, City shall pay Aleut the sum of Five Thousand Dollars ($5,000) upon execution of this Agreement. 3. Grant of Interest. Aleut hereby grants to City the exclusive right to conduct reconnaissance and exploration of the subsurface estate owned or controlled by Aleut on Akutan Island and its immediate environs, for purposes of evaluating the potential for developing geothermal resources for power generation, district heating and related applications. For purposes of this Agreement, geothermal resources include all forms of geothermal energy, including hot water, steam or gasses, hot brines, dissolved minerals, mineral materials, fluids artificially introduced into subsurface formations, heat or associated energy found beneath the surface of the earth, water from geopressurized zones, and other subsurface resources of whatsoever nature or kind wherever found, but shall not include petroleum or other hydrocarbons or sand, gravel and rock. 4. Production Agreement. When City's reconnaissance and exploration is complete, City will promptly present Aleut with a development plan that identifies prospective geothermal resource development options, and, if applicable, provide notice to Aleut of City's intent to proceed with resource development. In the event that City intends to develop one or more geothermal applications, Aleut hereby grants City the exclusive rights to negotiate with Aleut for development rights ("Production Agreement") for geothermal resources located within Aleut's subsurface lands, but not later than May 30, 2013. Subsurface Exploration Agreement-6/05/09 1 5. Operations. a. Aleut hereby grants to City the right to explore subsurface lands by geological, geophysical or other methods and, to the extent of Aleut's rights, to take water therefrom for operations hereunder. b. City shall comply with all federal, state and local laws and regulations applicable to its operations hereunder, and shall obtain all required permits, permissions, consents, or licenses. c. Upon expiration or termination of this Agreement, City will promptly remove all equipment and materials and shall restore Aleut's lands, as near as practicable to their original undisturbed condition. d. City shall indemnify, save harmless and defend Aleut from and against any and all liens, claims, judgments, or suits whatsoever arising out of activities or operations hereunder of City, its agents, representatives or contractors, other than those arising from Aleut's act or failure to act. e. City acknowledges that Aleut reserves all of its interests and rights in all geothermal resources as defined herein as well as all other natural resources. 6. Insurance. Prior to commencing operations on Aleut lands, City shall provide Aleut with a certificate of insurance for general liability and property damage insurance with limits of not less than $500,000 per occurrence and $1,000,000 aggregate for Bodily Injury and Property Damage, and Aleut shall be named as an additional insured under said policies. All such insurance policies and certificates shall include the following cancellation or change clause or a similar clause acceptable to Aleut: This insurance will not be cancelled by this insurance company, nor any changes made in the policy, without first giving thirty (30) days notice in writing to Aleut Corporation, 4000 Old Seward Hwy, Suite 300, Anchorage, Alaska 99503. 7. Termination. a. This Agreement may be terminated at any time by mutual agreement in writing by both parties. b. Failure by City to conform to the requirements of Section 5, Operations, or to maintain insurance as required by Section 6 of this Agreement shall constitute a material breach of this Agreement. Pursuant to any such breach, Aleut shall have the right to terminate this Agreement upon thirty (30) days notice to the City. City shall have the opportunity to begin in good faith to cure any such breach during said 30-day period and to complete remedial action within a reasonable period thereafter. 8. Force Majeure. City's obligations hereunder shall be suspended when City is prevented from complying therewith as the result of earthquakes, volcanic activity, tsunamis, strikes, lockouts, riots, action of the elements, delays in transportation, inability to secure labor or materials in the open market, laws, rules or regulations of any federal, state, municipal or other governmental agency, authority or representative Subsurface Exploration Agreement—6/05/09 2 having jurisdiction, litigation or administrative proceedings affecting title to lands covered hereby or operations thereon, or by other matters or conditions beyond the reasonable control of city, whether or not similar to the conditions or matters specifically enumerated in this section; provided, however, that unless otherwise agreed between the parties, City's obligations hereunder shall not be suspended for more than one year because of Force Majeure. 9. Severability. If any part, portion or provision of this Agreement shall be found or declared null, void, or unenforceable for any reason whatsoever by a court or governmental agency of competent jurisdiction, then only such part, portion, or provision shall be affected thereby and the remainder of this instrument shall continue in full force and effect. 10. Binding Effect. This Agreement and all of the terms, covenants and conditions hereof shall extend to and be binding upon the parties and their agents, representatives, employees, invitees and contractors. 11. Assignment. This Agreement may not be assigned without the written approval of Aleut which may be withheld for any reason. 12. Venue and Attorney's Fees. The venue for any civil action hereunder shall be the superior court in Anchorage, Alaska. The prevailing party shall be entitled to reasonable attorney's fees. 13. Notices. Any notice or other communication hereunder from Aleut to City shall be given in writing by sending the same by prepaid registered or certified mail with return receipt requested addressed to: City of Akutan Post Office Box 109 Akutan Alaska 99553 Any notice or other communication hereunder for City to Aleut shall be given in like manner to Aleut addressed to: Aleut Corporation 4000 Old Seward Hwy, Suite 300 Anchorage, Alaska 99503 14. Entire Agreement. This Agreement is completely integrated, represents the entire agreement with respect to the subject matter hereof, and supersedes any and all prior and contemporaneous contracts, agreements, promises, representations, warranties, inducements and covenants, oral or written, conditional or unconditional, expressed or unexpressed, recorded or unrecorded, which in any way arise out of, result from, are based upon or are connected with such subject matter. 15. Independent Counsel. Each party acknowledges that it had the advice and representation of competent independent legal counsel in negotiating, entering into, executing and delivering this Agreement; and the fact that this Agreement may have been drafted in whole or in part by one party's counsel shall not cause all or any part of this Agreement to be construed against such party. Subsurface Exploration Agreement-6/05/09 3 16. Recording. This Agreement shall not be recorded without both parties' written consent. IN WITNESS WHEREOF, the parties hereto have executed this instrument on this _ day of , 2009. The Aleut Corporation City of Akutan By: By: 101 i Troy Johnson, Joseph Bereskin, Chief Executive Officer Mayor By: Tracy Timothy Woo, Chief Financial Officer Subsurface Exploration Agreement-6/05/09 4 viar cv we v .oia LAP/ or AKutan yU/-eNtS-GLUM p.1 SURFACE USE AND EXPLORATION AGREEMENT This agreement is made by and between Akutan Corporation,hereafter referred to as "AC" and the City of Akutan,hereafter referred to as"City." WITNESSETH: WHEREAS;City wishes to have access to the surface estate of certain land on Akutan Island that it is owned by AC and specifically described herein for the purpose of undertaking a reconnaissance and exploration of the geothermal resources thereon; and WHEREAS, if the results of the said reconnaissance and exploration are favorable,City wishes to have the exclusive right to negotiate one or more long term lease agreements or other agreements for the purpose of developing geothermal power generation, and to construct one or more plants for the development of geothermal energy; and WHEREAS, AC owns title to the surface estate of the land on which the reconnaissance and exploration will take place; NOW,THEREFORE,in consideration of these premises and the mutual promises contained therein,the parties agree as follows: Article A. RECONNAISSANCE AND EXPLORATION 1. Definitions. Except as required otherwise by the context,the terms used in this agreement shall have the meanings indicated in this section: a. "AC"means Akutan Corporation. b. "City"means the City of Akutan, and when the context requires, its agents,employees,representatives,invitees and contractors. c. "Energy Project"means any geothermal power generation system as well as thermal-chemical utilization processes established,consisting of geothermal well sites, wells,piping, transmission lines,roads, and other appurtenances required to produce and transmit,heat,electricity, and related energy forms from one location to another. d. "Energy Resources"means all forms of geothermal energy including indigenous steam,hot water,and hot brines; steam and other gases, hot water,and hot brines resulting from water,gas,or other fluids artificially introduced into subsurface formations;heat or associated energy found beneath the surface of the earth;and water from geopressurized zones. e. "Project Area"means the surface estate of the following described land which is depicted on the map attached as Exhibit A,to wit: Surface Use and Exploration Agreement 1 w0a1 (-a vv ' .w/Ia ..uy UI Mr.U1.1�11 .7U( Q O-LLUL N,L i. Township 69 South, Range 112 West,S.M.,sections 30-36. ii. Township 70 South, Range 112 West, S.M., sections 4-9, and 16-18. iii. Township 69 South, Range 113 West, S.M., sections 24 and 25. And, both the surface and subsurface estate of the following land also depicted on Exhibit A, when it is acquired by AC from the United States,to wit: iv. Township 69 South,Range 113 West,S.M.. section 36. v. Township 70 South,Range 113 West,S.M. sections 1 and 12. f. "Reconnaissance Study"means a written analysis of the energy potential conducted on the Subject Lands in accordance with this Agreement. g. "Significant Surface Disturbance"means the removal of more than one(1) contiguous surface acre of material or vegetation from any specific site,or more than a total of one hundred surface acres from the Project Area. Crossing and recrossing the Subject Lands with all terrain vehicles,the blazing of trails,flagging of sampling sites, the establishment of temporary camps,and similar non-permanent activities of minimal nature shall not be deemed to constitute Significant Surface Disturbances. 2. Reconnaissance Study. a. AC hereby grants to City the right to conduct one or more Reconnaissance Studies of the Project Area during the term hereof for the purpose of evaluating the geothermal power generation potential thereon. City shall conduct all operations so as to minimize disturbance of the surface estate. b. AC hereby grants to City all necessary access to enter the Project Area so long as it is conducting its activities in conformance with the terms of this Agreement. c. AC hereby grants to City the right to explore the Project Area by geological,geophysical or other methods and, to the extent of AC's rights, to take water therefrom for operations hereunder. AC does not represent or warrant that it owns the water. d AC hereby grants City the right to use the surface for the purpose of supporting slim drill holes; geothermal gradient drill holes and exploratory holes into the subsurface geothermal resource. City and AC will consult on the specific location of all such holes and City will not drill in any location that is unacceptable to AC;provided that AC will not unreasonably withhold its consent to any such location. City shall obtain Surface Use and Exploration Agreement 2 the consent of the subsurface owner before drilling any holes or otherwise disturbing the subsurface estate. e. AC hereby grants to City the right to enter the Project Area and to take such samples and measurements as may be reasonably necessary to determine the appropriate location for the establishment of appropriate infrastructure in the Project Area. f. Notwithstanding the foregoing,City shall not have the right to undertake Significant Surface Disturbance or construct roads or make other permanent improvements in the Project Area during the reconnaissance and exploration period without the prior written approval of AC. g. City may temporarily store equipment in the Project Area necessary for its activities hereunder and shall have ingress and egress to and from the Project Area to carry out its activities hereunder; h. City shall obtain all required permits,permissions,consents,or licenses for any activities of City,and AC makes no representations or warranties as to the requirements for any such permits,permission, consents,or licenses or as to the availability of such. i. Nothing herein shall prevent AC, or its employees, agents, representatives, shareholders or invitees from entering the Project Area for any purpose that is not inconsistent with City's activities hereunder, including but not limited to, subsistence activities, and AC shall have such reasonable access to the Project Area as is necessary to properly monitor and ensure compliance with this agreement. 3. Term. The term of this Surface Use and Exploration Agreement shall be three(3)years from April 1,2009 to March 31, 2012 unless sooner terminated pursuant to Article B. 4. Payment. For the rights granted under this agreement City shall pay AC the sum of Five Thousand Dollars($5,000.00)upon the execution of this agreement. 5. Insurance. Prior to entering AC's land for any purpose, City,its agents, representatives and contractors,shall provide AC with certificates for general liability and property damage insurances from companies acceptable to AC with limits of not Less than $500,000 per occurrence and $1,000,000 Aggregate for Bodily Injury and Property Damage. a. All such insurance policies and certificates shall include the following cancellation or change clause or a similar clause approved by AC: This insurance will not be canceled by this insurance company nor any changes made in the policy, without first giving thirty (30) days notice in writing to Akutan Corporation,P.O. Box 8,Akutan,Alaska 99553. b. The insurance required under this agreement shall be maintained in full force and effect throughout the term of this agreement and any extension Surface Use and Exploration Agreement 3 -- ...Ir v. rvnULan `JU/-h`Jt5-LLUL p.4 City shallprovide AC with certificates of insurance before it or its agents,representatives, contractors or invitees enter AC's land for any purpose. 6. Operations. a. City shall comply with all federal,state and local laws and regulations applicable to its operations hereunder,and shall conduct all operations so as to minimize disturbance of the surface estate. b. City shall indemnify,save harmless and defend AC from and against any and all liens,claims,judgments,or suits whatsoever arising out of the activities or operations hereunder of City, its agents, representatives or contractors, other than those arising from AC's act or failure to act,and this section shall survive termination of this Agreement. c. City will reclaim and restore any surface disturbances for which it or its agents, representatives, contractors or invitees are responsible by restoring the land form and vegetation as nearly as practicable to their shape and condition prior to reconnaissance and exploration. 7. Labor and Materials. All of the labor performed and all of the materials furnished in City's operations hereunder shall be at City's sole cost and expense unless otherwise specified herein,and AC shall not be chargeable with or liable for any part thereof. 8. Testing. City shall be entitled to flow and/or blow wells for testing purposes in accordance with paragraph 2.d above. 9. Data. AC shall have the right to copies of all reports and studies developed by City under this agreement upon its request,including but not limited to the Reconnaissance Study prepared by City. 10. Agreements. a. When the City's reconnaissance and exploration is complete,the City wilt promptly present AC with a development plan that identifies prospective development options,and,if applicable, provide notice to AC of the City's intent to proceed with resource development. In the event that City intends to develop one or more Energy Projects, AC hereby grants City the exclusive rights to enter into a mutually acceptable lease with AC for land mutually identified by the parties. b. AC shall lease to City,pursuant to a lease agreement and price that is mutually acceptable to the parties,the smallest practicable tracts of surface estate that are reasonably necessary to construct and operate said geothermal project and shall grant to City the exclusive right to use said land to drill for, produce,extract,take,and remove geothermal resources from said land.Additional agreements may also be entered into, from time-to-time, as appropriate to develop and market geothermal resources. Surface Use and Exploration Agreement 4 1 l. Notices. Any notice or other communication hereunder from AC to City shall be given in writing by sending the same by prepaid registered or certified mail with return receipt requested addressed as follows: Hermann J. Tuna Scanlan,DPA City Administrator City of Akutan 3380 C Street, Suite 205 Anchorage, AK 99501 Any notice or other communication hereunder from City to AC shall be given in like manner to AC addressed as follows: Darryl Pelkey,President Akutan Corporation P.O. Box 8 Akutan,Alaska 99553 Article B. Miscellaneous Provisions. 1. Termination. AC shall have the right to terminate this agreement if City materially violates it. Failure to make any payments when due within a reasonable time thereafter, failure to provide proof of insurance, and failure to maintain required insurance policies shall, without limitation, constitute material violations of this agreement. Pursuant to any material violation(s), AC shall have the right to terminate this agreement upon thirty (30) days written notice to the City. City shall have the opportunity to begin in good faith to cure any such violation(s) during said 30-day period and to complete such remedial action within a reasonable period thereafter. 2. Force Majeure. City's obligations hereunder shall be suspended when City is prevented from complying therewith as the result of earthquakes,volcanic activity,tsunamis, strikes,lockouts,riots, action of the elements,delays in transportation,inability to secure labor or materials in the open market, laws, rules or regulations of any federal, state,municipal or other governmental agency,authority or representative having jurisdiction. litigation or administrative proceedings affecting title to lands covered hereby or operations thereon,or by other matters or conditions beyond the reasonable control of City,whether or not similar to the conditions or matters specifically enumerated in this section;provided,however,that unless otherwise agreed between the parties, City's obligations hereunder shall not be suspended for more than one year because of Force Majeure. 3. Waste and Environmental Contamination. City shall clean up and remove all waste and environmental contamination including but not limited to hazardous substances that are deposited on AC's land due to City's activities under this Agreement. "Waste"means without limitation all material for discard from City's activities,including but not limited to,human waste,trash, garbage, Surface Use and Exploration Agreement 5 p.o refuse,fuel containers,shot wire,survey stakes,explosives boxes, ashes and functional and nonfunctional property and equipment. 4. Fish and Wildlife. All activities hereunder shall be conducted so as not to adversely affect salmon, salmon streams,wildlife, fish and wildlife habitat,or the human and physical environment of AC's land. 5. Severability. If any part,portion or provision of this Agreement shall be found or declared null,void,or unenforceable for any reason whatsoever by a court or governmental agency of competent jurisdiction,then only such part, portion,or provision shall be affected thereby and the remainder of this instrument shall continue in full force and effect. 6. Binding Effect. This Agreement and all of the terms,covenants and conditions hereof shalt extend to and be binding upon the parties and their agents,representatives, employees,invitees and contractors. 7. Assignment. This Agreement may not be assigned without the written approval of AC which may be withheld for any reason_ 8. Venue and Attorney's Fees. The venue for any civil action hereunder shall be the superior court in.Anchorage,Alaska. The prevailing party shall be entitled to reasonable attorney's fees. 9. Entire Agreement. This Agreement is completely integrated,represents the entire agreement with respect to the subject matter hereof, and supersedes any and all prior and contemporaneous contracts,agreements, promises, representations,warranties,inducements and covenants,oral or written, conditional or unconditional,expressed or unexpressed,recorded or unrecorded,which in any way arise out of,result from,are based upon or are connected with such subject matter. 10. Independent Counsel. Each party acknowledges that it had the advice and representation of competent independent legal counsel in negotiating,entering into, executing and delivering this agreement; and the fact that this agreement may have been drafted in whole or in part by one party's counsel shall not cause all or any part of this Agreement to be construed against such party. 11. Recording. This agreement shall not be recorded without both parties' written consent. IN WITNESS WHEREOF, the parties hereto have executed this instrument as of the date first above written. AKUTAN CORPORATION kL Darryl Pelkey,President Attest: Ze B dilai -ot./ Borenin, Secretary Surface Use and Exploration Agreement 6 'VACYLLVG P., STATE OF ALASKA THIRD JUDICIAL DISTRICT THIS IS TO CERTIFY that on this!,c day of marc A ,2009,before me,the undersigned, a Notary Public in and for the State of Alaska, duly commissioned and sworn as such,personally appeared Darryl Pelkey and Zenia Borenin,known to me to be the President and Secretary, respectively,of Akutan Corporation. IN WITNESS WHEREOF, I have hereunto set my hand and official seal the day and year above written. Notary Public in and for Alaska My Commission Expires: 415,47164 CITY OF AKUTAN 11111LA-1 41, J.seph Bereskin, Mayor Attest: Amanda Tcheripanoff,City Clerk STATE OF ALASKA THIRD JUDICI.AL DISTRICT THIS IS TO CERTIFY that on this g q day of/ylarC ,2009, before me, the undersigned,a Notary Public in and for the State of Alaska,duly commissioned and sworn as such,personally appeared Joseph Bereskin and Amanda Tcheripanoff,known to me to be the Mayor and City Clerk,respectively, of the City of Akutan. IN WITNESS WHEREOF, I have hereunto set my hand and official seal the day and year above written. `tttttttttt(4,� • O ` ` 'OltN" '.4 Notary Public in and for Alaska ? My Commission Expires: 5, /cq di; Welly 1. �yns`ip��T-E of!". 'J,l1Jt771i1}1 Surface Use and Exploration Agreement 7 CITY OF AKUTAN UNIMAK ISLAND Anchorage Office AKUTAN 3380 C Street,Suite 205 Anchorage,Alaska 99503-3952 UNALASKA ISLAND ink Phone(907)274-7565 Fax(907)274-1813 UMNAK ISLAND ATTESTATION STATE OF ALASKA ) ss. THIRD JUDICIAL DISTRICT ) I, SUSAN LUTZ, being sworn, state the following: 1. I am employed by the City of Akutan as the Assistant Administrator and Deputy Clerk. 2. In the matter of the Designation of Operator, I hereby attest and acknowledge that Joseph Bereskin is the Mayor of the City of Akutan and is authorized to sign on behalf of the City as the designated operator for the oil and gas property as described. DATED this day of �_ , 2010. Susan Lutz Deputy Clerk SUBSCRIBED AND SWORN TO before me on this \ I day of 2010. y��-,CAL V!n���A�.' [notary seal] m ; /Any• I = Notary Pu l is in and for Alask ' : My Commission expires: `-\ STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMM. iON DESIGNATION OF OPERATOR 20 AAC 25.020 1. Name and Address of Current Owner of Record: City of Akutan 3380 C Street, Suite 205 Anchorage,Alaska 99503-3952 2.Notice is hereby given of a designation of operatorship for the oil and gas property described below: Legal description of property: Meridian Township Range _ Section Seward 70S 112W 5-7 69S 112W 32&33 70S 113W 1&12 Surface/Subsurface Agreements Attached Project Area Map Attached: Section Map Attached: ❑✓ 3. Name and Address of Designated Operator: City of Akutan; 3380 C Street Suite 205,Anchorage,AK 99503-3952 4. Effective Date of Designation: 24-Mar-09 5. Acceptance of operatorship for the above described property with all attendant responsibilities and obligations is hereby acknowledged (attach Power of Attorney or other evidence of authority of person signing): Signature Date Printed Name Joseph Bereskin Title Mayor-City of Akutan 6. The Owner hereby certifies that the foregoing is true and correct(attach Power of Attorney or other evidence of authority of person signing): Signature Date Printed Name Joseph Bereskin Title Mayor-City of Akutan 7. Approved: Commissioner Date Approved: Commissioner Date Approved: Commissioner Date (Requires approval by two Commissioners) Form 10-411 Rev.7/2009 Submit in duplicate SIETE DT ALASEA SEAN PARNELL,GOVERNOR ALASKA OIL AND GA,S 333 W.7th AVENUE,SUITE 100 CONSERVATION COMl►IISSION ANCHORAGE,ALASKA 99501-3539 Robert E. Kirkman PHONE (907)279-1433 FAX (907)276-7542 Technical Services Manager City of Akutan 3380 C Street, Suite 205 Anchorage, AK 99503-3952 Re: Hot Springs No. 2 Exploratory Geothermal Well, Akutan Island City of Akutan Permit No: 210-071 Surface Location: 2325' FEL, 500' FSL, S. 32, T69S, R112W, S.M. Bottomhole Location: 2325' FEL, 500' FSL, S. 32, T69S, R112W, S.M. Dear Mr. Kirkman: 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 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, Daniel T. Seamount, Jr. Chair DATED this z3 day of June, 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 ALA_ .A OIL AND GAS CONSERVATION COMM. ..)N PERMIT TO DRILL RECEIVED 20 AAC 25.005 la.Type of Work: lb.Proposed Well Class: Development-Oil ❑ Service- Winj ❑ Single Zone ❑ 1c.Sim&i w is cased for: Drill El Redrill ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Coa at 131 Gas Hydrates n❑ Re-entry ❑ Exploratory Service- WAG ❑ Service-Disp ❑ G Il �heSS10FY 2.Operator Name: 5. Bond: Blanket Q Si e Well d Mill{e�a.,nn�n pThmber: City of Akutan Bond No. 5/62,-X- /' Hot SpriWEm�" 3.Address: 6.Proposed Depth: ZY 12.Field/Pool(s): 3380 C Street Suite 205,Anchorage,AK 99503-3952 MD: 1500 ft. TVD: 1500 ft. 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Hot Springs Bay Valley Surface: '-,2,32_S/'- L 5cc, f=,6L S 62 �,46 ' / `=z - /Yet .' ��',i , /lb Top of Productive Horizon: fZ%(L'v V 8.Land Use Permit: 13.Approximate Spud Date: 6,`ib{Z- 5.A-t: Subsurface Agreements(CPQ-Attachment C) 10 July 2010 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: '`bu c /<_1> 1/4 Acre N/A L•iL./c� 4b.Location of Well(State Base Plane Coordin tes-NAD 27): 10.KB Elevation above f 81 feet 15.Distance to Nearest Well Open Surface:x- 5.3/2572_, y- $(v LA Zone- GL Elevation above I 77 feet to Same Pool: N/A --688A863.,�,� /C,it, �3'52 ..../z,'/6 16.Deviated wells: L_16A./0 Kickoff depth: feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 0 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 TVD (including stage data) 9.875 6.625 24 K55 Mod BTC 33 0 0 33 33 11.6 cu ft w/20%excess,tremie 5.5 4.5 11.2 HWT-4130 MBT-FJ 150 0 0 150 150 15.4 cu ft w/100%excess,single stage c 3.78 3.5 7.67 HQ-4130 MBT-FJ 600 0 0 600 600 13.6 cu ft w/100%excess,single stage c 2.98 1.5 3.02 ASTM A-53 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 TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat ❑ BOP Sketch❑✓ Drilling Program Q Time v.Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements❑ 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Printed Name Robert E.Kirkman Title Technical Services Mgr. Signature te� / Phone (360)259 9570 Date June 15,2010 Commission Use Only Permit to Drill API Number: _ Permit A ro n ' See cover letter for other Number: ,L�0 7� 50-2-9 •2 C(7 (=O- c, Date: 7� �i b requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed t"�thhaaaaane,gas hydrates,or gas contained in shales: 2/ Other: Samples req'd: Yes M No❑ Mud log req'd: Yes []/No ❑ H2S measures: Yes[� No❑ Directionalnsvy req'd: Yes ❑ No [ � *-=i.%L]crv4.-(z�;v,_ .:71(_r02 L' it te[r�,! J '(• 6.,,/Co'/1_' /z13 // oDATE: i APPROVED BY THE COMMISSION j ,COMMISSIONER ORIGINAL , RECFNEDf I Ativ to - cfo Ico 14AAAA • r' L6 I3 STATE OF ALASKA ,, ..',I ALASKA DIVISION OF OIL AND GAS Alaska til zi ;a.3 cons,(;0mmission PERMIT TO DRILL `1ie(0 11 AAC 87.030 and 11 AAC 87.070 la.Type of W .Current Well Class: Exploratory ❑ Development Oil ❑ 1c.Specify if well is proposed for: Drill Q Redrill ❑ Stratigraphic Test ❑ Service ❑ Development Gas ❑ Coalbed Methane ❑ Gas H .rates ❑ Re-entry ❑ Multiple Zone ❑ Single Zone ❑ Geothermal EShale Gas ❑ 2.Operator Name: 5. Bond: Blanket ❑ Single Well Q 11.Well -me and Number: City of Akutan Bond No. HSB i ell No.2 3.Address: 3380 C Street Suite 205,Anchorage,AK 6.Proposed Depth: 1 . ield/Pool(s): 99503-3952 MD: 1500 ft. TVD: 1500 ft. 4a. Location of Well(Governmental Section): 7.Property Designation: Surface: Hot springs Private Land Top of Productive Horizon: Uncertain 8.Land Use Permit: 13.Approximate Spud Date: Subsurface Agreements(CPQ-r 'achment C) 8/1/2010 Total Depth:1500 ft. 9.Acres in Property: 14.Distance to Nearest Approx 1/4 Acre Property: N/A 4b.Location of Well(State Base Plane Coordinates-NAD 83): 10.KB Elevation above SL: 45 feet 15.Distance to Nearest Well Open Surface: x- y- Zone- KB Elevation abo e GL: 3 feet to Same Pool: N/A See Attached Drilling Program and Plan 16.Deviated wells: Kickoff depth: feet 17.M lmum An' ipated Pressures in psig: Maximum Hole Angle: degrees Down l9 - Co SCJ Surface: 490'SQS- 1 18.Casing Program: Specifications 1To; - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length 1 Av1D ND MD ND (including stage data) 8 1/2 7 '- \, 0 20 20 3.1 c.f.class G cement 4.827 4.5 11.3 Ib/ft HW 4 threads/in 5 ft sectkJ 0 150 150 36 cf 3.782 s. 7 , 19. PRESENT WELL CONDITION SU Y o be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs a .re\d)�. Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length i : ze, \� Cement Volume MD ND Conductor/Structural \v Surface � \. Intermediate Production !' Liner q Perforation Depth MD(ft): Perforation Depth ND(ft): 20. Attachments: Filing Fee BOP Sketch Q Drilling Program Q Time v.Depth Plot ❑ Shallow Hazard AnalysF Property Plat Pr Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program ❑ 11 AAC 87 requirement❑ 21. Verbal Approval: Commissio -epresentative: Date 22. I hereby certify that the fore.•ing is true and correct. `! /^Contact �! Printed Name I A !r W 0> p •/MAt. t/ Title 19g©�r'�� /, Argi t-G-Fe 1� --- Signature 111 Signature -4.— r���XXXX� rII" Phone (0 Z--(/15-5-3 Date 2...210....--, I Q Division of Oil and Gas Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: 2 IP t� 7( 50-L'7S -7E,L 1- - Date: requirements. If box is checked,well may not be used to explore for,test,or produce coalbed meth e,gas hydrates,or gas contained in shales:2 Conditions o,approval: Samples req'd: Yes[✓ No Mud log req'd: Yes 2/No❑/ Other: H2S measures: Yes ElNo❑ Directional svy req'd: Yes ❑ NoLrJ �-� �(G tit int-1-7e,-i-c 6 ,ruel Fe e teed 1.7e4- IIiitt L g 7! )I APPROVED BY THE DIVISION OF OIL AND GAS DATE: ,COMMISSIONER Geothermal Permit to Drill 7-2009 This permit is valid for 24 months from the date of approval(11 AAC 87.070(d)) Submit in Duplicate ORIGINAL. Ln co O h 4J H H H 3 \ co " b, `n • H aV til E. • ^ Z O N W o i d co Gl ul "Jr4 1 — -.jilt E � ,i\\ 4� •'/( ./ s O ��` 1t j � ' fs 1i , O 1. i :i 1 '�' �. 1�- �• r � 7 3 r ; t 0 _ �\ `! ly .rsY 11,1 1 // , j O ,ti xL •2\' �.�ii -r-, r —_,-,4-i -✓ C y< T /1 �M„ � / i '' �. •'s 4° .rl' •, % tt4 r((1/4/.1f/ I\ ' . . '\\tr--I < - N \ ll, l ‘ e r ., f l�� tit{ `�i fir=+ .L1. tr i �fi i'''';r t 'Al 4' ! ' , 99t,..-- \-� --�— o '')!!;)41114,-..-'-. ' -,t/...,..{'). I, git, ?lift i*ii i.' . : I 11 a, , .\‘s, 1,.. i LO). 2 r • y /;� t {S1 ,:;. •);rr o00#-'1. ... . i .t.i.„: ) r:.4 1 0 a) ;:". Of"; ''''46. o 111 l o , o �1 N 4 Ig a w h ` d ry ` .... H 1. H y/ �p v, m -� �' .iii_' ! m n, N \ `; I O Op {a EL o c ;co H opco :+ `�.\1•`_ \'1 ii 'A' H •�I . N m:r 1 IF �'!�� _ 0 vs E 1 LE li e - •I- 'if , . ,_, N 3 O H A H \ "I • (NJ W in W H H M er H `a •. H in ,y -, ry .. 3e W 3 44 Akutan Test Well Project k440 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 I Yield 2.16 cu ft/sack Total: s�','Excess /',' ;; G None cc R • 5 sacks ccement, c#c„ 33 ft • 140 lbs silica flour 12.7) • 14 lbs CaCI, 6.62E in Csg f' • 56 gallons of water 24.00 lbm'ft `. 33 ft / ' I! i — Mone 4.5" Casing 2.74 bbl i -- 5.500 in 4 . Premium II 13.5 ppg cement w/30 % Silica Flour and 100%Excess /.Y 2% CaCI 1E0 ft / f.'l • 11.144 gallons water/sack J • Yield 2.15 cu ft/sack 4.400 in Csg /' .;1 7;a ' Total: 9•50IbrNft (•': • 7 sacks cement .`f"7 14ci4C 1E0 ft ,l • 200 lbs silica flour !; ':' • 13 lbs CaCI • 78 gallons of water 3.500 in CT 'i 3.5" Casing 9.6410m� f ft � t i.. 600 ft /. Premium II 13.5 ppg cement w/30% Silica Flour and ;; None 0.75% retardant 3.780 in j I 2.43 bbl ■ • 11.068 gallons water/sack r Excess • Yield 2.13 cu ft/sack c 6 / l Total vib o't-� I • 6 sacks cement • 170 lbs silica flour • 4.25 lbs retardant (Halad 413 equivalent) • 66 gallons of water Akutan Test Well Project Hot Springs Well Drawn by A.Bailey.GRGI 5/25/2010—Not To Scale 3M Casing Head Flange with/ 3M Tubing Hanger and 1-W 1000 psi Steam Service Valve 5-1/2" Oversize PQ Core to 150' N,/ 4-/2 HWT 11.2#/ft 4130 Butt Casing to 150' Burst Pressure — Box Shoulder = 2656 psi , / Burst Pressure — Midbody = 6218 psi 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) 1-1/2" 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 N C4 o CO 6-5/8" x 14" riser t 1 0 0 7-1/16 3M _/ 00 Annular Preventer to M M t` N I < w N., > NOD O W 6" 900 Exp. Gate Q K Z. N Valve w/GT Trim n cD i ___ _ I X X CD N X DT A CD OD SD = 0 co T � � ID i (.1) CD k \I CD -- CV I �' \ \\ U Cellar - 72" Diameter BoartLongyear Energy Products Group t*0 OPERATOR City of Akutan WELL NAME Hot Springs (1,500' TD) LOCATION Akutan, AK SUR. CSG. 6 5/8" @ 30'; 41/2" @ 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 1/2" (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 1/2" core rod or casing. 600'- 8.5.19.Q* 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 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 Geolilerillal 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 Hot Springs Well Drilling Program 1. Build location with cellar and site sump to suit core drilling rig. Move in drilling rig. 2. Perform a pre-spud safety and operations meeting. 3. Drill 9-7/8" diameter hole to+30 ft from bottom of cellar. Take returns to wellsite reserve pit using cellar pump. 4. 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". 5. Cement conductor 5.1.Run tremie pipe and mix and displace cement into the 9-7/8"x 6-5/8" annulus. 5.2.WOC(wait on cement) until surface grab samples are set. 6. Install Thread-on Riser. 6.1.Line up mixing tub on riser via centrifugal pumps and 2"side outlet valve on lower part of riser. 6.2.Install flow line to mud pit via 3" outlet at top of riser. 7. Pick up P rods and core ahead from to+/-150 ft. 7.1.Follow the mud program while drilling use 8.9 pound per gallon mud and maintaining 9.0 pH. 7.2.Note lost circulation intervals and immediately report lost circulation to the drilling supervisor. 7.3.Be prepared for artesian flow throughout rotary drilled interval. 7.3.1.1f artesian flow occurs, mix weighted mud using CaCI and Barite. 7.3.2.If weighting mud is insufficient to kill the well, mix neat cement and spot cement across zone. 7.4.Collect and box 10 foot core samples as per geologist's instructions. 7.5.Run a drift shot with MRT at 100 foot intervals. 8. Run and cement HWT core casing to surface. 8.1.Circulate and condition hole for casing. 8.2.POH & lay down P core rods. 8.3.Run and cement HWT(4-1/2" OD) core casing to surface. 8.3.1.Install float above 10' shoe joint. 8.3.2.Make up landing joint. Land casing as needed to set top of HWT core casing 1 foot above bottom of cellar. 8.3.3.Cement using 100%excess as per cementing program.Take returns through 2"side outlet on riser. Displace cement and bump plug. 8.3.4.Take returns through 2" side outlet on riser. 8.3.5.Back-flush cement out of riser bottom through 2"side. 8.3.6.WOC 9. Back off landing joint and pull riser. Clean up threads on riser. Perform top job, if needed. 10. Make up wellhead assembly. 10.1. Thread on 4" 900 wellhead. 10.2. Nipple up 4" 900 x 7-1/16"3M DSA. 10.3. 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. 10.4. Function test annular preventer, kill line, and diverter line valves. 11. Test BOPE to 750 psi. 11.1. Test casing, kill line,and diverter line valves to 750 psi. 11.2. RIH with flared PQ test joint and test annular preventer to 750 psi. 11.3. 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. 12. Pick up HQ rods and wireline core from to+/-600 ft. 12.1. Perform formation integrity test. 12.1.1. Drill out float and shoe track and clean out cement. 12.1.2. Drill ahead making 20 feet of new hole. 12.1.3. Apply surface pressure to annulus to an equivalent 0.625 psi (12.0 ppg)gradient. 12.1.3.1. Apply pressure at 0.1 bbl/1 minute increments. 12.2. Follow the mud program while drilling. 12.3. Monitor flowline temperatures constantly. 12.4. Note lost circulation intervals and immediately report lost circulation to the drilling supervisor. Maintain water on the backside to prevent flashing. 12.5. Be prepared for artesian flow throughout rotary drilled interval. 2 12.5.1. If artesian flow occurs, mix weighted mud using CaCI and Barite. 12.5.2. If weighting mud is insufficient to kill the well, mix neat cement and spot cement across zone. 12.6. Collect and box 10 foot core samples as per geologist's instructions. 12.7. Run a drift shot and MRT at 100 foot intervals. 13. Run and cement HQ(3-1/2") core casing to surface. 13.1. Circulate and condition hole for casing. 13.2. POH & lay down P core rods. 13.3. Run and cement HQ core rods. 13.3.1. Install float above 10'shoe joint. 13.3.2. Make up landing joint. Land casing as needed to set top of HQ core below wellhead flange. 13.3.3. Cement using 100%excess as per cementing program.Take returns through diverter liner. Displace cement and bump plug. 13.3.4. Back-flush cement out of wellhead riser bottom through diverter line. 13.3.5. WOC 14. Back off of landing joint and nipple down wellhead assembly. 14.1. 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. 15. Make up the wellhead assembly and function test the annular preventer and side outlet valves. 16. Test BOPE to 750 psi. 16.1. Test casing, kill line, and diverter line valves to 750 psi. 16.2. RIH with flared PQ test joint and test annular preventer to 750 psi. 16.3. 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. 17. Make up NQ rods and wireline core+/-1500 ft. 17.1. Perform formation integrity test. 17.1.1. Drill out float and shoe track and clean out cement. 17.1.2. Drill ahead making 20 feet of new hole. 17.1.3. Apply surface pressure to annulus up to an equivalent 0.625 psi (12.0 ppg)gradient. 17.1.3.1. Apply pressure at 0.1 bbl/1 minute increments. 17.2. Follow the mud program while drilling. 3 17.3. Monitor flowline temperatures constantly. 17.4. Note lost circulation intervals and immediately report lost circulation to the drilling supervisor. Maintain water on the backside to prevent flashing. 17.5. Be prepared for artesian flow throughout rotary drilled interval. 17.5.1. If artesian flow occurs, mix weighted mud using CaCI and Barite. 17.5.2. If weighting mud is insufficient to kill the well, mix neat cement and spot cement across zone. 17.6. Collect and box 10 foot core samples as per geologist's instructions. 17.7. Run a drift shot and MRT at 100 foot intervals. 17.8. If bottom hole temperatures in excess of 425 deg F are encountered, it will be necessary to cement the NQ rod in place and reduce to BQ. 17.9. If torque or wellbore stability becomes a problem, reduce to BQ. 18. Upon reaching TD,follow Pressure/Temperature Logging Procedure. 19. Run tubing into well and hang from the wellhead. 19.1. RIH with tubing to near bottom. 19.2. Make up a landing joint and hang the tubing in the mast. 19.3. Kill the well thoroughly using cool water or weighted mud. 19.4. Unbolt the crossover from the wellhead and lift to get access to the tubing joint. 19.5. Slip a spade plate underneath the tubing collar and land tubing on the plate. Back off landing joint. 19.6. Make up tubing hanger flange and land on the wellhead flange. 19.7. Nipple up the flanges and close the top valve. 20. Release rig. 4 Akutan Geothermal Project 2010 Exploratory Well Drilling Program and Drilling Plan Program Elements 1. Two to four slimholes will be drilled in Akutan's Hot Springs Bay Valley for temperature gradient measurements. If fluid is encountered, flow tests will be conducted and fluid samples taken for chemistry analyses. Up to three of these wells will be drilled to total depth (TD) of 1500 feet and a fourth, to 3500 feet (see Figure 1). 2. The drilling contractor will use a heli-portable or other small wireline core rig and take continuous core throughout the drilling process. 3. With the exception of a possible a few tens-of-feet of overburden, drilling will be through competent volcanic rock and wellbore stability will therefore not be a problem (although lost circulation could be). 4. The drilling platform will consist of an approximate 25' x 40' pad constructed of 2" x 6" boards laid on edge and held together by threaded steel rods. 5. Sites will be located near a water source that will provide a continuous water supply for both drilling operations and camp needs. Water will be pumped by electric pump. Water will either be pumped into a holding tank on location or just used directly. 6. A light duty track excavator (E.G. Kubota KX41-3V or similar) will be helo-transported to and between each drill site. This machine will be used for site preparation, construction of the drilling cellar and containment ponds. 7. An area large enough to accommodate the facilities, equipment and supplies shown in Figure 2 will be cleared of overburden and leveled for drill site activities. An earthen berm will be built around the perimeter and lined with an impenetrable material for containment purposes. 8. The area designated for fuels storage will be prepared with a primary containment barrier, and the entire area will be lined with an impenetrable containment material (see Figure 2). 9. Camp(s) will be established within walking distance to the drill sites. The rig, the camp, and other supplies will be transported between sites via helicopter. 10.The camp will include tent cabins mounted on raised wood platforms, portable toilets and portable showers. All contaminates will be contained and transported from the site. 11.All wells will be drilled with an annular blowout preventer (BOP). Drilling Locations (See Figure 1) Well 1, at the top of the valley, is the highest priority well as it is believed to be near the upwelling zone for the geothermal fluid or at least on its margins. Therefore, very hot temperatures could be encountered at depth. Well 1, willed be drilled to a total vertical depth (TVD) of 3500 feet. Well 2, near the hot springs, is the next highest priority. The site appears to be located in the center of the outflow zone, where two different tabular aquifers could be penetrated at relatively shallow depths. This well will be drilled to 1500 feet. Wells 3 and 4 will also be drilled to 1500 feet. They appear to be located in the outflow zone and will provide constraints on the geometry, temperature variations, and flow patterns of the outflow. Drilling Site A cellar, with an approximate maximum dimension of 7' x 7' x 7', will be dug for the rig to sit atop (actual cellar size will be limited by geologic conditions). The cellar will have cement or timber walls and a floor, constructed of plywood and 2" x 4" frame. Steel or wood beams will be fitted underneath the rig. This and the rest of the site elements are shown in Figure 2. Drilling Operations This task will take approximately 4 months, June - September 2010. Core, cuttings, pressure/template data, and other information will be collected from the boreholes during the drilling phase. The slimholes will be designed following the profiles presented in Figure 3. The drilling plan will be conducted as follows: 1. Construct a cellar, approximately 7' x 7' x 7', and organize site and sump, move in rig, rig up. 2. Drill 8 '/2" hole to 20 feet and cement in 7" casing. 3. Drill PQ hole to 150 feet and cement in HW casing. 4. Drill HQ hole to 1500 feet. If necessary cement in HQ casing and continue drilling with NQ size hole. 5. Core collected through production intervals and logged by the well site geologist, if encountered. 6. Stand NQ rods in hole. 7. Run temperature logs. 8. Pull NQ rods from hole. 9. Flow test well if well is capable of flowing. 10.Run flowing temperature and pressure logs in well and collect water and/or noncondensible gas samples. 11.Shut in well. 12.Abandon well in accordance with Alaska regulations (fill with mud to 10 ft. from surface, plug top 10 ft. with cement). Camp Water extraction will be from the nearest water source adjacent to the well site. A series of tents with wooden platforms will be constructed so that they can be moved from camp to camp with minimal breakdown (see Figure 2). Mud/Refuse Disposal Since we are collecting core from the wellbores, the amount of return material will be minimized. The maximum amount of cuttings ejected from the hole will be approximately one-inch surface area per foot. Therefore, for a 1500-foot hole, we would get approximately 1500 cubic inches of return material and 3500 cubic inches for the 3500-foot hole. Used drilling mud will be flowed into a series of connected cooling and settling tanks. As mud gets hotter, mud will be flowed first into a cooling sump then into the tank system. Another sump will be dug for containment of contaminated mud. These will be large (-20' x 30' x 6' sump for the deep hole, —20' x 15' x 6' for the shallow holes). Mud will sit in the disposal sump for a day or two, with water decanted off the top to maintain freeboard. Soil dug from the sump will be stockpiled nearby and used for later abandonment. Containment ponds will be as close to the drilling platform as reasonably possible, but in all cases will remain a minimum of 100' from the nearest stream or water body. Fluid Disposal The composition of the fluid will determine its disposal (all activities will comply with federal EPA and/or State DEC regulations). In the case of substantial fluid returns, the standard method of disposal is to dig pits (known in the industry as "cattle troughs"). The plan calls for digging three such troughs, 2 feet deep, 2 feet across and 12 feet long. If the fluids contain substantial sediments, a series of water tanks could be used to settle it out prior to disposal in the pits. Mobilization/Demobilization and Transport Helicopter support is planned for the duration of the drilling activities. For this reason, two different core rigs may be deployed simultaneously to reduce helicopter expense and to account for a shorter drilling season. The size of the helicopter needed will be determined by the heaviest piece of the drill rig and/or the weight of the track excavator that will be needed for site preparation. It is assumed that a helicopter with a lift capacity of 3500 pounds or more will be required. 4111\ Approx.80'X40' SS Gal.iielStorage Or rs Generator Containment Area - - drainage Core storage 40'X25'Wood Platform Porta (2'X6'Boards On Edge) Potti 1 Sump For Mud Disposal a )To Be Located A N Minimum of 100' E Drill Rig --• From Any Streams 2 Operatiors N "ertOn Or Water Bodies) — 0 Raiser, Q fY ter,ars `^ Woos Pumps l Pipe Stor. I Materials Platform Storage drainage • 0 0 6 00 11110/ ii ii Containment Berms Porta Potti 6 Mar'ert6 Mar.Tent Dinin Generator g/Medic On Raises Wood On Raised Tent Porta Platform Wood Platform0 Potti Portable Shower Figure 2. Conceptual diagram of individual wellsites for the Akutan exploratory geothermal drilling program including: maximum equipment; life support materials and drainage sump planned to be located on-site. 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) — 1— _20' — L— _20' PQ hole; PQ hole; HW casing HW casing (4.5"O.0.) (4.5"OD.) — — —150' —150' HQ hole HQ hole uncased HW casing (3.782"dia.) (3.782"dia.) —1500' —1500' Annular Blow Out Preventor DiagramNQ hole \ uncased accumulator (2.750"dia.) water oloil =.00.000storage ABO• 6"valve —3500' Figure 3. Profile of individual wellbore designs for the Akutan exploratory geothermal drilling program. qlbGeothermal 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 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 ,...... N..: LFTM 90C Core Drill 0411‘..4Technical Data Sheet May 2009 Page 1 of 6 PRODUCT OVERVIEW Working from the proven LF'"90 long stroke platform,the LF""90C hydraulic diamond core drill comes equipped with • a Cummins Tier 3 engine to meet today's stringent emission requirements.We have standardized on the hydraulic system.as well as controls and other components from the LF`"90D drill. - " FEATURES: / • Cummins QSB 6.7 L Tier 3 engine provides you with the /" power you need. • Patented Nitro Chucks—offers you performance and = ' ii— reliability(1 year warranty). �. - • Independent dual mast raising cylinders. L4 - II , . Y a • 11 ft feed stroke and 16,000 lb mainline hoist improves , - productivity and increases depth capacity. 2 • • Upgraded control panel for improved ergonomics. /� r LFTM 70 LFTM 90C/ LF" 90D LFTM 230 '4;kk ' A kJ 4`.., / t :; DRILLING DEPTH GUIDELINES The figures in these tables have been calculated,based on 7 258 kg(16.000 Ib)hoist(single line pull).Actual drilling field experiences,and may be reasonably expected. Ratings capacity will depend on in-hole tools.conditions.drilling are based on a vertical.straight.clean down hole using a techniques and equipment used. DRY HOLE FLUID FILL ED DRILL ROD/CORE BARREL ale Depth(meters) '' _—- Depth(feet) Hole Depth( -- Hole Depth(feet) BRQ/BQ 1210 IL 3,968 ' 1 385 4,543 , BRQTK/BQTK 1 523 4,995 1 744 ' 5,722 , NRQ/NQ/NQ2 930 AL_ 3,053 1 064 3,492 ' NRQ V-WALL'" 1 052 Irk- 3 451 --w l 1 193 I 3,915 ' HRQ/HQ r 631 ' 2.071 722I 2,370 ' HRQV-WALL'" _ 2,607 l` 898 -6111112717=11 PHD/PO =__211_7______11: 1 368 476 _� YL 1562 PHD V-WALL'" 568 jE 1 865 =r 637 --17![ 2.089 Always verify manufacturers rod depth ratings prior to use. Boar,Longyear is cnoslanlly striving to improve Its products ano mus,therefore.reserve toe rigor to change designs,matellels,speottostions and price wufloot notice. Copyright 02000 BOART LONGYEAR.All Rign,s Reserved r � LFTM 90C Core Drill Technical Data Sheet C*0 May 2009 Page 2 of 6 TECHNICAL SPECIFICATIONS METRIC SYSTEM U.S.CUSTOMARY SYSTEM PRIME MOVER Standard Unit Cummins QSB 6.7 L, liquid cooled,turbo charged,after cooled,diesel engine Displacement 6.7 L 409 in3 Power(maximum)at 2,200 RPM 153 kW 220 hp Emissions Certification Stage III Tier 3 TORQUE AND RPM RATINGS (Hydraulic motor at maximum/minimum displacement,prime mover at 2,200 RPM) Speed(no load) Torque(stall) RPM Nm lbft 1st Gear 122- 199 5 322-3 254 3,925-2,400 2nd Gear 246-400 2 648-1 620 1.953- 1,195 3rd Gear 439-714 1 486-908 1,096-670 4th Gear 769-1,250 849-519 626-383 NOTE: Head output speed and torque are infinitely variable in each gear range as indicated. Actual rotation speed is affected by engine RPM and hydraulic motor displacement setting. HYDRAULIC SYSTEM Primary Pump Axial piston,variable displacement load sensing,pressure compensated with low pressure standby. Max Flow 165 L/m 43.5 gpm Maximum Pressure(factory setting) 31 MPa 4,500 psi Secondary Pump Axial piston,variable displacement load sensing,pressure compensated with low pressure standby. Max Flow 64 L/m 17 gpm Maximum Pressure(factory setting) 21 MPa 3,000 psi Auxiliary Pump Axial piston,variable displacement load sensing, pressure compensated with low pressure standby. Max Flow 42 L/m 11 gpm Maximum Pressure(factory setting) 14 MPa 2,000 psi Hydraulic Tank Capacity 231 L 61 Gal DRILL HEAD Standard PQ-Hollow Spindle Rotation Motor Rexroth hydraulic motor-variable/reversible Mechanical Transmission Funk 4 speed Ratios 1st 6.27:1 2nd 3.12:1 3rd 1.75:1 4th 1.00:1 Boarl Longyear is constantly Owing I0 Improve its graduate and must IIerelore,reserve the right io change designs.materielsspeclllcatlons end puce without notice. Copyright 02000 KART LONGYEAR.All Rights Res,,,,0 LFTM 90C Core Drill 0144Technical Data Sheet � May 2009 Page 3 of 6 TECHNICAL SPECIFICATIONS METRIC SYSTEM U.S.CUSTOMARY SYSTEM DRILL HEAD(cont'd) Final Drive Straight cut gears Ratio 2:1 Head Opener Pivot style—manual operation Patented Nitro-Chuck® Hydraulic PQ Chuck Hydraulically opened, nitrogen gas spring closed. Axial holding capacity of 222 400 N(50,000 lbf) Drill Head Lubrication Force fed bearings,oil bath for gears Drill Head Lubricating Oil Filtration 25 micron high pressure oil filter T AND FEED SYSTEM Feed Stroke 3.35 m 11 ft Feed Pull 111 797 N 25,133 lbf Feed Thrust 58 957 N 13,254 lbf Rod Pull 6 m 20 ft Drilling Angle 45°off horizontal to 90°vertical down Mast Dump(Crowd) N/A I N/A DRAW WORKS Main Line Hoist Single speed motor Hook Load(single part line) Bare Drum 7258 kg 16,000 lb Hoisting Speed(single part line) Bare Drum 53 m/min 173 ft/min Main Hoist Cable 15 mm 0.59 in Minimum Breaking Strength 23 042 kg 50,800 lb NOTE: Do not use multiple part lines with the main line hoist, use single part line ONLY. Foot Clamp Capacity HWT I Wireline Hoist Level Wind N/A Line Pull Bare Drum 993 kg 2,190 lb Full Drum 228 kg 502 lb Line Speed Bare Drum 145 m/min 475 ft/min Full Drum 433 m/min 1,422 ft/min Drum Capacity 1 890 m 6,200 ft (4.8 mm/3/16"swaged) Minimum Breaking Strength 2 268 kg 5,000 lb NOTE:Wireline cable length to be specified at time of order. ADDITIONAL INFORMATION Fuel Tank Capacity 176 L 46 Gal Boort LongYear Is conslenhy slriving to Improve its protlucta antl must theretoie,reserve the right to change assigns.materiels,apectliceticrrs an0 price wlihout notice. Copyright b2009 BOART LONOVEAR.All Rights Reserved LFT" 90C Core Drill r1 Technical Data Sheet 6/0 May 2009 Page 4 of 6 DIMENSIONS AND WEIGHTS* WEIGHT Wet Weight=5 656 kg(12,469 Ib) Consisting of: Power Unit Group Cummins QSB 6.7 L,Tier 3,6 cylinder Hydraulic Module Draw Works Grp.c/w 16,000 lb Main Line Hoist and Wireline Hoist c/w cable Hydraulic Mast Raising(Independent) Lower Mast Assembly 3-Piece Lattice Mast Assembly Rotation Unit Grp.c/w PQ Nitro-Chuck°/Head Guard Base Frame Fuel Tank 190 L/50 US gal) Battery-12V Operator Platform Hydraulic Foot Clamp-HWT Capacity OPTIONS Rod Racking Platform WARNING: Do not operate this drill with rods racked in wind velocities in excess of Hydraulic Leveling Jacks Towing Group-Dual Torque Flex NOTE:Not highway rated Axles(oscillating) Hot Weather Hydraulic Cooling Group CE Certification Decals available in multiple languages Fluid circulation pumps (diesel supply and pressure) Mud mixer DRILL TRANSPORT POSITION C/W OPTIONAL TOWING GROUP 5321 mm (17'5") 111 -+ Ir IL�.=�•�`�%���1%� 2014 mm ifs__ _r,ir'�i�c. (6,7") 2433 mm it=d;,g It~\.. I I (711) 110 \�a lli\ +I �. '=0—cr' 1 I 6 4 mm (21'7") 1 �2 3(76797_•1 69)m_•1 *Dimensions and weights may vary depending on options and should be checked before crating or lifting. Boah Lon9Yeascnnsla5'- t. i,iv- . i .nii .t .Iri. .•,.t iii c n iii i . .sl... . - iil ii..v' ii.riIvri4 .)U,p(,nNIt NGVf nfi A 1 .I .i.,l ._. LFT" 90C Core Drill1 r1 Technical Data Sheet t* May 2009 Page 5 of 6 DIMENSIONS AND WEIGHTS* DRILL-MAST AT 90° NOTE:Dimensions are with optional towing group and hydraulic leveling jacks extended to ground level. Leveling jack full stroke is 914 mm(36 in). th II/I LI I1 WI I\ I, I l 10 287 mm Irk;iI I (33'9") ;I\ I�III I*I 14. „AL II 11.11-1111,w Mill I�1. °,:„...i �ir_ 1 IIIill i. _ el O - —.e�- ImI- • 6068mm _ 14 (19'11") H 2 36(7797;m 'I *Dimensions and weights may vary depending on options and should be checked before crating or lifting. Boerl Longyeel is conslengy siRving to improve lle prod,,Is end must I�elelole,reserve 10e IiyM1l to cM1anyc 90090*malellals.speclllcellol�s end p,,00 vilM1oul noM1c� Copyright 02009 BOARI LONGYEAR.All ROB Reserved. LFT" 90C Core Drill Oitl Technical Data Sheet111110 May 2009 r,u1E 6 e=6 DIMENSIONS AND WEIGHTS* (W11)FLUID CIRCULATION PUMP GROUP(OPTIONAL) Wet Weight=254 kg(560 Pb) Aminummoh. id) -F ___ 0 The max.output of the standard 2-speed ■�� '/ r 7.7% j motor of the W11 is as follows: !! I High vol./low pres.35 gpm 300 psi 6.2 hp IMI.i`II�I�I L �(1'"'P1. P11 ` see mm Low vol./high pres.17 gpm @ 800 psi 7.9 hp 748 mm I' -.f0:110:43:- ( '3") limaimial If a higher output pressure system is required , an optional 2-speed motor can be supplied ��� Ikale-01617 I with the following max.output: High vol./low pres.23 gpm @ 950 psi 12.7 hp 14 914 mm Low vol./high pres. 11 gpm @ 1000 psi 6.4 hp (3') (1.09)FLUID SUPPLY PUMP GROUP-DIESEL(OPTIONAL) Wet Weight=145 kg(320 Ib) The max.output of the standard 2-speed i= n 7fi:momm T T, + ,---- motor I ' in 9 pres. gpmpsi11 0 1i,� I 4s2 mm •� ). (2'2'') Low vol./hi vol./high -109P800pf I ( tun I High vol./low pres.-20 j `\ Clii III on.NMI- 1197 mm 14 (3'S")J . MUD MIXER ASSEMBLY(OPTIONAL) Wet Weight=31 kg(68 Ib) ,1 NOTE: Maximum speed of the mud mixer shaft at full flow is LA � 2300 rpm. - 111 C.;" 5;"' 1 219 mm �� - T (4) Cit.1 381 mm Ash\ I T I381 mm 4- (1.3..) *Dimensions and weights may vary depending on options and should be checked before crating or lifting. Rneii Loogyeai is coosianly striving to npi.vu its Iietlo•Ix noJ novl Ilioniura.rceerve Ilii Rgito clino90 tlosig,*.nieloiialn.sponiioetions antl pRoe wilttouantic•- Gopyrgfhl OR 2009 ROARI LONGVEAR.All Rights Reserved 0 GeolilerInal 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 Geothermal Resource Group, Inc. The Geothermal Resource Group, Inc. provides exploration,drilling and reservoir expertise to assist in the drilling, completion and operation of geothermal projects, as well as the project planning and completion of regulatory paperwork. Bill Rickard and Paul Stroud formed the Resource Group consulting firm in July 1992. Now the Geothermal Resource Group, Inc. (DBA Resource Group) is carrying on the tradition of excellence that started over 15 years ago. Resource Group is realizing the original goal of providing a complete geothermal resource development service to the industry. The goal of the Geothermal Resource Group, Inc. is to provide cost effective services to our customers in the geothermal industry. Our customers in the industry will be able to initiate, complete and operate more geothermal projects using our services.This will help ensure the viability of our customers in the geothermal industry. We feel that our job is to provide a service to help maximize profit.The best way to do this is with good planning and supervision. The group now consists of Bill Rickard working with two drilling engineers and two project managers, who as individuals represent well over 100 years of experience in the energy resource business. The ten drilling supervisors we currently work with have more than 200 additional years of experience. We have geothermal management,exploration,drilling,work over,testing, production, reservoir simulation and resource management experience.We have dealt with low temperature fields where the wells must be pumped to fields with the highest temperatures and pressures encountered in the industry. Sincerely, William M. Rickard/President March 27, 2009 1 Our Services Drilling D g • Well design,drilling and remediation. • Preparing drilling and work over programs. • Preparing permit applications to submit to the appropriate federal,state and county agencies. • Interfacing with regulatory agencies as required and authorized by the Client to obtain approvals on applications. • Supervising the preparation and submission of well completion reports. • Analyzing available data to determine the most efficient drilling practices. • Developing less expensive,more efficient drilling practices to reduce drilling costs. • Selection of drilling rig supervisors after consultation with and approval of the Client's management. • Preparing cost estimates for drilling and remedial work. • Assist in selecting cost effective methods and vendors for drilling applications. • Maintaining appropriate well records, review daily drilling reports and prepare daily entries to the drilling history. li Drilling Supervision: • Coordinate the efforts of all service companies. • Prepare daily drilling reports for management review. • On site supervision of all critical operations. • Delegation of supervision to appropriate personnel. • Gather input from all appropriate service companies and the client's management to determine the most appropriate course of action. • Make recommendations to the Client's management concerning all major decisions in drilling operations. • Make recommendations to the Client's management concerning drilling engineering decisions. • Use available equipment in the most efficient manner to maximize the rate of penetration. • Balancing all drilling variables to maintain the maximum rate of penetration. Drilling Training: • Planning and scheduling the training,required by regulatory agencies or client. • Contracting for geothermal well control school for all contract and client personnel. • Training supervisors in safe and efficient drilling practices applicable to the client's project. Reservoir Engineering: • Production well testing(safety,flow measurement,deliverability,wellhead power available). • Injection well testing and evaluation(injectivity, identification of injection zone). • Decline analysis,differentiation between reservoir decline and scale. • Evaluation of cased hole problems and development of work over programs. • Reservoir modeling,simulation of production and injection scenarios. • Well bore simulation,optimization of casing size,deliverability curves. • Reservoir assessment. 2 Exploration and Project Development: • Exploration and project planning and tracking. • Resource assessment. • Mapping,geophysical testing and geochemical sampling and analysis. • Temperature gradient well drilling and logging. • Lease appraisal and land acquisition. • Planning and permitting. • Bidding for services and vendors. • Project cost estimates. • Road building,site development and remediation. Regulatory Compliance • Mechanical Integrity Testing, programming and analysis. • Underground Injection control compliance inspection. • Document review,document and permit preparation. • Injection well conversion. Can Geothermal Resource Group Inc. really help your company reduce project costs? Here's a real example.... A prominent geothermal company had drilled a number of wells with the assistance of several different drilling engineering firms before contacting Geothermal Resource Group. In each case, the costs for these wells had far exceeded their budgets and the wells had not reached the planned depths. Progress had been so slow that scheduling the other aspects of the project, including construction of the power plant, had been postponed. Geothermal Resource Group Inc., by using superior planning, supervision and technology, was able to reduce the average cost per foot by nearly 43%, while at the same time increase the average total depth by 80%. The average number of days spent drilling each well was decreased by 21%, while the average feet drilled per day increased by a stunning 95%. Non—productive time was reduced by 63%. The improvements in supervision, planning and project management introduced by Geothermal Resource Group allowed the client to bring in additional drilling rigs and complete production well drilling ahead of schedule. Greater well depths resulted in higher line temperatures,which will greatly increase the productivity of the power plant and ultimately increase the profitability of the client. In addition to increasing drilling efficiency, Geothermal Resource Group, Inc. made a number of improvements to the design of the wells. Among these improvements was the redesign of the casing program, including casing grades, weights, connections and setting depths. Additionally, superior cementing slurries and techniques have been used to improve results at a reduced cost. These changes will result in reduced maintenance of the well field. Decreasing the need for working over and cleaning out existing wells will dramatically reduce maintenance costs over the lifetime of the project. Key Personnel William"Bill"Rickard President Bill Rickard has over 30 years' experience in drilling engineering and consulting. He specializes in project management,drilling management, rig supervision,troubleshooting,well workovers and problem well diagnosis. He has an established record of reducing costs through innovative engineering, and successfully managing geothermal exploration and drilling programs. Bill's experience,working as a drilling engineer in the US and overseas, has given him the ability to communicate well with both management and hands in the field. He has also used his knowledge to develop and teach geothermal drilling technology and other technical courses,and conduct geothermal research and development efforts. Prior to starting his own company as an independent geothermal consultant, Bill worked almost 15 years for Unocal Geothermal. He has a Bachelor of Science degree in Petroleum Engineering, and has also completed multiple geothermal reservoir engineering,drilling safety and management training courses. Bill is a registered Professional Engineer(California No. P001722)and holds other professional certifications. He has served on the Geothermal Resources Council Board of Directors,and is a member of the American Association of Drilling Engineers,and Society of Petroleum Engineers. Abraham "Sam"Samuel Drilling Engineer Sam Samuel provides design of geothermal wells and pre-drilling programs. He also acts as a drilling supervisor on-site during drilling and workover operations. Sam maintains well records and analyzes drilling data for efficient drilling practices,and makes recommendations to clients' management teams regarding drilling and operations. His experience includes geothermal engineering and well design work in New Zealand,supervision of geothermal mudlogging operations in Indonesia, and work on high pressure and high temperature wells throughout Southeast Asia. He also has experience coordinating and implementing HSE policies during drilling operations, maintaining a RIMBase database,and preparing and analyzing final well reports. Sam holds a Master of Science degree in Petroleum Technology and a Bachelor of Science degree in Chemistry as well as a Drilling Supervisor Certificate-Surface BOP Stack. He has also completed Mud Engineering School and a Drilling Practices Course. He is a member of the Geothermal Resources Council,Society of Petroleum Engineers and the American Association of Drilling Engineers. 4 Wendell "W.T." Howard Drilling and Reservoir Engineer W.T. Howard has been a contract drilling engineer for many years,working in geothermal resource development. He has experience with designing drilling programs,supervising drilling and completion of geothermal wells, and managing drilling operations,while supervising day-to-day activities on location. W.T. also has extensive well testing experience in geothermal operations,and experience as a geothermal production/reservoir engineer. W.T. has worked in numerous areas, both in the US and overseas. He has written project specifications, forecast and managed budgets, performed cost analyses,written procedures,trained drilling engineers, and supervised the installation of geothermal turbines. His extensive background in all phases of geothermal projects gives him the ability to manage all aspects of clients' drilling programs. W.T. holds an IADC drilling certificate for Drilling Supervisor-Surface Stack and a Bachelor of Science degree in Mining Engineering. He is a member of the Geothermal Resources Council and Society of Petroleum Engineers. Alan Bailey Geologist/Coordinating Supervisor Alan Bailey is a highly experienced geothermal drilling and exploration professional with more than 20 years of industry experience. Alan has worked as a geologist, drilling operations manager and drilling supervisor. He has proven ability in meeting organizational goals and objectives, is pragmatic and quality-focused, and has excellent project management skills. Alan has worked on numerous geothermal projects in the United States and Latin America. He has supervised drilling operations, written drilling plans, budgets, planned geophysical surveys, overseen health and safety, road and access development, site remediation and is well-versed in the preparation of permits and other government documents. He also is highly experienced with geothermal well testing. Alan has a Bachelor's Degree in Geology and is currently working toward a Master's Degree in Management. He holds an IADC WellCap well control certificate for Surface Stack—Supervisor, Drilling, and Workover& Completion. He has completed a Drilling Supervision course and project management coursework. Alan is a member of the Geothermal Resources Council, Society of Petroleum Engineers, the American Institute of Professional Geologists and the American Association of Drilling Engineers. He is also a member of the Project Management Institute. 5 Benedicto Alarcon Drilling Engineer Benny Alarcon has more than 30 years of geothermal experience in The Philippines, Indonesia and North America. Benny has worked as a drilling engineer,drilling manager, reservoir engineer and field operations manager on a wide number of projects. He has particular expertise in geothermal reservoir stimulation and improving well performance. In addition to reservoir stimulation, Benny has written drilling,completion and workover programs, budgets and AFE's for new and existing projects, and managed field operations. Benny has a BS in Chemical Engineering, and has completed coursework in drilling, drilling supervision, casing design,cementing and other drilling engineering processes. Benny has also attended mud school and taken project management courses. He is a member of the Society of Petroleum Engineers,the Philippine Institute of Chemical Engineers,and the Geothermal Resources Council. Associates to Geothermal Resource Group: Cal Stroebel Reservoir Engineer Cal Stroebel is one of the most respected members of the geothermal community,with nearly 40 years of experience working in oil&gas and geothermal exploration. A graduate of Montana Tech and of Stanford University,Cal has worked on geothermal prospects worldwide, including in Indonesia,South America,and in the United States. In 2009,Cal Stroebel was awarded the Henry J. Ramey Jr. Geothermal Reservoir Engineering Award recognizing his outstanding achievements in the field of geothermal reservoir engineering. Cal is available to the GRGI team on a consulting/contractual basis. Richard Holt Reservoir Engineer Richard Holt specializes in using reservoir simulation,wellbore simulation,and detailed analysis to assess geothermal resources, make forecasts, and find optimizations. He has the ability to design, implement,and analyze well tests and reservoir tests to help clients successfully develop geothermal resources. His years of experience have taken him to many different geothermal fields, covering a wide range of complex settings. Richard develops comprehensive and accurate reservoir simulation models for clients to serve various purposes, including simulating and comparing various operating scenarios,assisting in monitoring well deliverability and finding optimum operating strategies, and for use in power plant design and power purchase negotiations. Prior to working with GRGI, Richard worked with Unocal,the Mesquite Group,and FPL Energy. He has both Master and Bachelor of Science degrees in Petroleum Engineering. 6 Richard is available to the GRGI team through a partnership with his specialized geothermal reservoir engineering consulting firm,Geothermal Science,Inc. Bill Ehni Geologist Bill Ehni received his Bachelor's degree in Geology from Humboldt State University in 1975. He has been professionally employed as a geologist since 1975. Bill is the founding president of the AAPG-affiliated Nevada Petroleum Society and has been actively involved in petroleum and geothermal exploration in Nevada since 1985. Bill has more than 30 years of experience in geothermal exploration and development. His specialty is the integration of geology with geophysics for construction of accurate models used in drilling and developing geothermal resources. He has been directly involved with the geology at numerous geothermal power plants. These include the dry steam field at the Geysers, California, high salinity geothermal systems in the Imperial Valley, California, the geothermal system at Casa Diablo power plant near Mammoth Lakes, California, and numerous other geothermal, oil and gas and mineral prospects in California and Nevada. Bill, with his wife Vicki, operates Ehni Enterprises, Inc., which offers services to the geothermal, petroleum, mining, and geotechnical industries. These services include geological consulting, geophysical surveys (resistivity, magnetic, self-potential), geological well-site supervision and geologic surface mapping. Ehni Enterprises also maintains a large database of maps dealing with the geothermal, oil and mineral potential of Nevada and publishes a periodic newsletter, the Nevada Oil Reporter, which provides information to the petroleum and geothermal industries. Bill is available to the GRGI team through a partnership with his specialized geothermal consulting company Ehni Enterprises Inc. • Bill Rickard, WT Howard, Benny Alarcon and Sam Abraham will perform drilling engineering. • Drilling supervisors are Tom Atkison,Tony Auren, Brian Watson, Mike Barry, Billy Doyel, Andy Auld, Ron Donnelly,Jeff Potter, Kevin Katolas, Randy Baldwin, Billy Gaches, Pat Hartzel and Dan Darnell. Sam Abraham and Alan Bailey are also available for drilling and other site supervision. • Coordinating supervisor is Alan Bailey. • Bill Rickard, WT Howard,Alan Bailey and Richard Holt set up well testing. • Research and training may be performed by any of the above personnel, and will be priced accordingly. Rates for each specialty will apply as required. • Richard Holt will perform reservoir modeling. 7 Our Clients Include... • Fairweather Pacific,LLC • Geologica,Inc. • Ormat Technologies,Inc. • Presco Energy,LLC • Geothermal Development Associates • Southern California Gas Company • Iceland America Energy,Inc. • Nevada Geothermal Power Co. • Meager Creek Development Corp. • Geoglobal Energy,Inc. • Nevada Dept.of Transportation • Sierra Geothermal Power Corp. • Martifer Renewables • HL Power Company • Pinnacle Gas Resources • Unocal Corporation • Mammoth Pacific LP • Unocal Geothermal Indonesia • Global Power Solutions • FPL Energy • Big Horn Gas • Mount Wheeler Power • CET Environmental Services • Terra-Gen Power • El Salvador CEL • Oceanit • Ormat Technologies,Inc. • KBE Energy • Calpine Corporation • Water Resources International • Puna Geothermal Venture • U.S.Department of Energy • CHAR LLC/Hudson Ranches,Inc. • Sandia National Laboratories • U.S.Geothermal,Inc. • Constellation Energy Group • Northwest Geothermal Company • Caithness Energy LLC • CalEnergy Generation Corp. • Polaris Geothermal,Inc. 8 Contact Information Geothermal Resource Group,Inc. Office Phone: 760-341-0186 PO Box 11898 Office Fax: 760-341-9673 Palm Desert,CA 92255 Email: Bill Rickard: billrickard@geothermalresourcegroup.com Sam Abraham: samabraham@geothermalresourcegroup.com Wendell Howard: wendellhoward@geothermalresourcegroup.com Alan Bailey: alanbailey@geothermalresourcegroup.com References: Organization: Baker Hughes Address: 5510 Skylane Blvd. Santa Rosa,CA 95403-1029 Phone: (707) 523-1751 Point of Contact: Nic Nickels,Manager of Geothermal Operations Nic.nickels@inteq.com Organization: California Division of Oil,Gas,and Geothermal Resources Address: 801 K Street,MS 20-20 Sacramento,CA 95814-3530 Phone: (916)445-9686 Point of Contact: Ali Khan,District Engineer Organization: Department of Land and Natural Resources,State of Hawaii Address: State Office Building,Rm 204 75 Aupuni St. Hilo,HI 96720 Phone: (808)974-6210 Point of Contact: Erik Tanaka,Engineering Inspector Eric.a.tanaka @ hawai i. Organization: US Geothermal,Inc. Address: 1505 Tyrell Lane Boise,ID 83706 Phone: (208)424-1027 Point of Contact: Doug Crea,Drilling Manager dcrea@usgeothermal.com 9 Organization: US Geothermal,Inc. Point of Contact: William Teplow,Senior Geologist wteplow@usgeothermal.com Organization: Terra-Gen Power,LLC Address: 9590 Prototype Ct. Suite 200 Reno,NV 89521-5916 Phone: (760)413-9196 Point of Contact: Fred Wilson,Drilling Superintendant fwilson@terra-genpower.com Organization: Pacific Mountain Contractors/Peppermill Casinos,Inc. Address: 243 Brinkby Ave. Reno,NV 89509 Phone: (775)826-4411 Point of Contact: Terrence Spampanato,Vice President&Technical Manager Terrence@pacific-mountaincontractors.com Organization: Ormat Technologies,Inc. Address: 6225 Neil Road Reno,NV 89511-1136 Phone: (775)356-9029 Point of Contact: Paul Spielman,Manager of Operations Support pspielman@ormatcom Organization: Enel North America Address: 1755 Plumb Lane Reno,NV 89502-3600 Phone: 775-786-5681 Point of Contact: Greg Davidson,Field Operations Manager Greg.davidson@northamerica.enel.it Organization: Halliburton Energy Services Address: 1990 Hays Lane Woodland,CA 95776 Phone: (530)666-0233 Point of Contact: Jerry Evanoff,Geothermal Account Leader Jerry.evanoff@halliburton.com 10 Conditions of Approval City of Akutan HSBV Well No. 2 (PTD 210-071) 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- r-- proved. AiI .s-f o -a,,,� s al is S do rs re H.cv d. 6. Test BOPE to 750 psi on a seven-day frequency. Ci')../+ ` / o ��W4:4 ,"74,1,%‘,-^,1) �, "I •,�1 L E o ": X , -? ii. , n i 1 ; - c' Z 11t 1 �`) g1 IP-- ..4.14. d► 4 r C ' }� � t_ fes Q 1+`, a '',' ii 1 ) '4-7.-'Itl'''''^‘ r,,'70 . - . .,,,,,.....:----) ) I( u _,`l J , it 4, J) , Y ' m " GD 4u �� 7 ♦f �'� v ' Illa:11': ' ' I'4°•• )i.; 1,50‘ C' I , ` k f ) $ f 4.)�r M1 t 444 �` '. Ti]' 4(‘ tr$ 1 i 1 7 2://it; ' * --, ' 1,‘.-'I', ( : i J W a 111 r j5 .. to 4a• k1 - ✓• +�. ././ 11 V); 2 Ln N # - -fir- --1 .i. JP Anomer- ' r _ r lry ' ',,,IC, 1� } i, ii, 'L\\°� �Nt4.��, 1-3 4-•- 11' 141.3• — �• 1 ...._--..--J..- N of Lf) — j 2 oo ` 4 r / -" %,,,,,,,), ' 5 ' ), . 4 *'6 •kr 0:1 ul M 0. ))i , . fit i �'.1;'�l `�; \ a) C\'.1� `` ,tea , t'"` l ( 0 ? r'' r- �` `i � ,.. w !- AAAA �e•'1 � i _ � �, a) ..-, '',1:,'a--.-- /( f ( , 11 -t- ' , — i/ - ..., D --',,-- , f•--, ' , 0 0 w,, )'\I")1 i 1 )//27.7:1:ii\;'N. / :-: ---- , , ', �'r� it';:-..SN% 11 1 N:;: iil -'*1 f= ��� i'4,;7V.-- 1 �.����j.i{t1 / r f� � c� O 1 � a. to 10 2 461 c41 vs=' p1 =1 , t LIJ I I D r_I I i^l 00 o ▪ N l0 M CO 0 C Ln N N Lf) a r-1 o oo o0 00 00 U LA to LK; Lf1 • to l0 lD lD f0 rI r-1 r-I ri )e Y a N CO N • o LO 00 00 ct O O 2 co Ln m m • a+ o co m Ln LO m m m N Ln m ri r I • 4 4 4 4 Ln Lf1 Lfl L.fl l0 M 441- Ln N p ON N00 N t0 N l0 M O^1 Ul > 0 00 00 00 00 C J Ln Ln Ln Ln 0 l0 LD LD LD U ri ri ri 71 C • ri M N Let 4.C4 4141 M e-I Cl N 00 N Lo0 0l N m LLfl U a+ N M .4:1- Ln 4:tLfl r1 m m J rI ri ri 00 4 4 Ln O Ln Ln Ln 1 Q N 01 rl CO LD W G1 0l 0 0 Ln N „ N IN 0 O 01 ECoI : N -43 g o0 00 00 00 LC Li) Lt.) Ln In 0 0) l0 lD lD lD L 0 00 ri ri ri ri U vl -C LID CD CO �00 LLD .r-I N a, °C ,. N L O v ca I M00 •O m O J r-I r-I-I .-I rM-I 4-' O. Z Ln Lin Lin CI3ri 0m ri Q 0 >. IN 01 O0 CO N' LD N O D: In Ln lfl In 00 C N vt l0 00 N X Ln N Ln CL m c-i N lD N N M N N In Ln In Ln IN � IN N N N N ri r1 r-I ri ri ri r-1CC CC CC CC CC ri H N N N Ln In 0 O 0 0 IN IN `) 17 H H H 7 LD N l0 N • 0 m O 0 ro In N N N Ln 0 0 0 0 U LL CONI Ln 001 rLn i C7 ri r1 Ln 0 Q w w UJ UJ - Ln Ln 0 0 LLI N N In CO LL N. M 00 N •:1- e-4 :tri w J - O Q! CC N m -- c m m m LL z z z AOGCC AKUTAN 14 June 2010 INPUT OUTPUT Geographic,NAD27 Geographic,NAD83 Accuracies of conversions from NAD 27 to NAD 83 are typically 12 to 18 cm. FUMAROLE 1 1/4 Latitude: 54.143786164523 Latitude: 54.142917614 Longitude: 165.890249913335 Longitude: 165.892220633 Datum Shift m. : Delta Lat.=-96.676,Delta Lon=128.787 HSBV 2 2/4 Latitude: 54.1546161668924 Latitude: 54.153748330 Longitude: 165.85420010819 Longitude: 165.856175277 Datum Shift(m.): Delta Lat.=-96.597,Delta Lon=129.044 HSBV 3 3/4 Latitude: 54.1439915127224 Latitude: 54.143123195 Longitude: 165.871900750239 Longitude: 165.873873396 Datum Shift(m.): Delta Lat.=-96.650,Delta Lon=128.912 HSBV 4 4/4 Latitude: 54.1384325767251 Latitude: 54.137564141 Longitude: 165.875995553114 Longitude: 165.877967150 Datum Shift(m.): Delta Lat.=-96.663,Delta Lon=128.861 Remark: NAD 27(RBDMS-generated)to NAD 83 Coordinate Conversions-SFD 6/14/10 Corpscon v6.0.1,U.S.Army Corps of Engineers I, Notes—Akutan Geothermal Wells, Permit to Drill Applications The four geothermal well permit applications were entered into RBDMS, and a permit checklist was generated for the Fumarole No. 1 well. The well identification numbers are: Fumarole No.1 Permit 210-070,API 50-295-20001-00-00(this is the first well in the Unimak Quad) HSBV No. 2 Permit 210-071,API 50-295-20002-00-00 HSBV No. 3 Permit 210-072, API 50-295-20003-00-00 HSBV No.4 Permit 210-073,API 50-295-20004-00-00 Davies' Comments: 1 The bond submitted is a DNR, DOG blanket bond for$200,000. It would be best if the City of Akutan re-did this bond (prior to drilling) using an AOGCC form in favor of the AOGCC, else problems will arise in the event of default or if additional wells are drilled in the future. 2.The AOGCC normally requires a Designation of Operator form when the operator is different than the owner(unless the lease was acquired at a State or Federal Sale). On this form, a representative of the operator clearly accepts all obligations and responsibilities for the well and drilling operations. Are John/Tab okay with just accepting the Subsurface Resources Exploration Agreement in lieu of a Designation of Operator form, or should we request the form be submitted? (I recommend requesting one.) 3. Per 11 AAC 87.070(6)(2), a legal description and map of the parcel[s] and well location[s] is needed. The simple map supplied is clear, but it is not adequate. Legal descriptions and state base plane coordinates are missing from the permit to drill forms. AOGCC's required legal descriptions are footages specified in metes and bounds(FNL, FEL, Governmental Section,Township, Range, Meridian), not in lat/long coordinates. AOGCC's required coordinates are State Base Plane referenced to NAD 27.The permit to drill form used specifies NAD 83, and we can get by for now, but in the future, NAD 27 coordinates should be required. An as-built survey plat with these coordinate sets must be required as part of the Completion Report submittal. I'm assuming that the lat/longs supplied are referenced to NAD 83, so I converted them to approximate legal descriptions (accuracy is about 100'). These rough legal descriptions are: Fumarole No.1 3400' FNL 4100' FEL Sec. 6,T70S, R112W, SM ASP Zone 8, X=524205.4 Y=52577.1 fO HSBV No.2 250' FSL 2350' FEL Sec. 32,T69S, R112W, SM ASP Zone 8, X=531225.3,Y=56239.5 ! t' i(9 HSBV No.3 3650' FSL 600' FEL Sec. 6,T70S, R112W,SM ASP Zone 8,X=527714.2,Y=52333.1 HSBV No.4 200' FNL 1750' FEL Sec. 7,T70S, R112W, SM ASP Zone 8, X=526568.6,Y=50501.2 When converted and plotted in Geographix, these coordinates agree reasonably well with the simple map supplied by the operator. But, again, a final as-built plat showing each well must be required. 4. Are the maximum anticipated pressures correct for Fumarole No.1? Assuming an 8.4 ppg freshwater gradient, shouldn't the pressure at 3500'TVD be about 1500 psi and the anticipated surface pressure about 1150 psi? 5. H2S measures are not mentioned in the Title 11 geothermal regs, but are included with the check boxes on the bottom of the permit to drill form. I'm assuming that such measures are not considered nec-ssary for geothermal wells. I left the boxes unchecked. Ste - P. June 10, 2010 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 ,„ It)27.( WELL NAME - go V --� PTD# „ I Development Service V Exploratory Stratigraphic Test Non-Conventional Well FIELD: tfri(L/i POOL: (�//(de 117,c '(2)i (e r ( 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. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. 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