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Home My WebLink About210-072 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. 02 I Q - 007a Well History File Identifier Organizing(done) ❑ Two-sided Ill I1111111111111 ❑ Rescan Needed lUll IlilU 111111 R CAN DIGITAL DATA OVERSIZED (Scannable) Color Items: ❑ Diskettes, No. ❑ Maps: �Greyscale Items: ❑ Other, No/Type: ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: i BY: Date: r _. 3 /st Project Proofing 11111111111111 BY: Maria Date: 1.1131111- /s/ MP Scanning Preparation I x 30 = 3 0 c5� + = TOTAL PAGES 3 ^ (Count does not include cover sheet) BY: Date: l ci�.,3 /(� /s/ Production Scanning I Stage 1 Page Count from Scanned File: Zt(J (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: /ES NO BY: Maria Date: //49.31 I if /s/ p Stage 1 If NO in stage 1, page(s)discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. I IIIIIIIIIIIII ReScanned I 1111111110 VIII BY: Maria Date: /s/ Comments about this file: Quality Checked III IIFII III IIII III 12/22/2011 Well History File Cover Page.doc o c 0 f6 o M °m . ri O o N N Z ° a ... = InN C E Z j ` 0 N i o m -°I s, E. I co c m y o o v a) o 2 I Q I c m Q 0_, o o > E m= CC .c a a) m N o' a ! m u) d Us o w 1 o fr o� w I � 4 "c 'EI E c ° ,t-_ E N' a y c = _ SEE ca �/ .1c U U y w Ce c O Z .5 f° a+ a Z Z CL Q Q U R N ENE } >- H W Y I Z l) I' cc Q c t LLI j N ! P• I! o II WI H 1 U U N w I i o° I aQ N W Z C I. • 'J a. ° _ • 0 .N o Q. p Z f H 03 0 J r fo •— N ti d O N_ ca E a J N O 0 E ti co J ' � I -�— I— J II Q 1I i J w $ i � 1 � j 1 H j 0 I I' 03 0 J I' to t (1) `° cn Q o Z ° a) k) Q Q r �� Z E 1// D E °U J 1 z 7 11 d c E 'i I co 1 cc z 0 1 W `° z O) E o n p E y a Z Z Z v v O Q Z r C W O Z N 0 )- >- >- d o N O P o co °' z v d z 2 V ` ,+�� E 0 CO J N cc 0 « O1 N z a ... .a) V o W d c D a) ayi Z as a°) I C ° . ,... et ? w o `o O o O . > °) 1° H U E a E 5 Q y J U n > "y cu a w ! Q N o(0T ¢ U Q ! U U ! 0 H 3 J 0 ►- 3 ; I • St',\IfE CIF ALASEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 Raymond R. Mann PHXONE (907)279-1433 (907)276-7542 Program Manager City of Akutan 3380 C Street, Suite 205 Anchorage, AK 99503-3952 Re: Akutan Undefined Geothermal Well, North Elbow Well #3 City of Akutan Permit No: 210-072 Surface Location: 1975' FSL, 855' FEL, S. 6, T70S, R112W, S.M. Bottomhole Location: 1975' FSL, 855' FEL, S. 6, T70S, R112W, S.M. Dear Mr. Mann: Enclosed is the approved application for permit to drill the above referenced geothermal exploratory well. This permit application is approved contingent upon the following conditions: 1. Well operations shall be conducted in accordance with 20 AAC 25. 2. Pursuant to 20 AAC 25.035 (h) (1), alternate BOPE is approved. 3. Pursuant to 20 AAC 25.035 (h) (2), the diverter requirement is waived. 4. Pursuant to 20 AAC 25.061 (c), the near surface survey requirement is waived. 5. Pursuant to 20 AAC 25.066 (d) (3), alternate gas detection equipment is approved. At least one methane detector and one H2S detector are required. 6. Test BOPE to 750 psi on a seven-day frequency. 7. Pursuant to 20 AAC 25.020, a Designation of Operator form (Form 10- 411) and accompanying Powers of Attorney must be filed with the Commission within 60 days. Pursuant to 20 AAC 25.071(b)(2), dry cuttings samples must be submitted to the Commission. The preferred sample interval is 10', with a maximum of 30'. A final as-built survey plat showing the location of the well at the surface 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. Since - / j IS.Dagot -amount, Jr. Chair DATED this 2,1/day of July, 2010. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) Wok STATE OF ALASKA Veto 20{o ALA ,OIL AND GAS CONSERVATION COMMI: IN RECEIV� PERMIT TO DRILL 20 MC 25.005 JUN 2 9 2010 1 a.Type of Work: lb.Proposed Well Class: Development-Oil ❑ Service- Winj ❑ Single Zone ❑ 1 c.Specify if well is proposed for: Drill 161 • Redrill ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone EAgIIh�l1iiiiSSin1 Re-entry ❑ Exploratory el' Service- WAG ❑ Service-Disp ❑ Geotherrnamchge Gas ❑ 2.Operator Name: 5. Bond: Blanket 0 Single Well ❑ 11.Well Name and Number: City of Akutan Bond No. c/72-- 74, is 1,,iTe,..4 NorthElbowWell/3 3.Address: 6.Proposed Depth: 12.Field/Pool(s): / 3380 C Street Suite 205,Anchorage AK 99503-3952 MD: 1500 ft. TVD: 1500 ft: Ak'uk,t a'kizrc.,,..&`7e-b, "u-`4rq) 4a. Location of Well(Governmental Section): 7.Property Designat' n(Le se, umber): HotSpiings-Bay-Veiley ' A Surface: -"- /'?7.�( L� 8�S f FL J 5.�I IZ�S Jj'1(zlc� -`,'- _ Al e li l�I,/, / {,.,.; 6 3e) ft. Top of Productive Horizon: v,ate- a.Al 8.Land Use Permit: ( ' 13.Approximate Spud Date: Subsurface Agreements(CPQ-Attachment C) 8/5/2010 Total Depth: ��ie 9.Acres in Property: 14.Distance to Nearest Property: 7 /* ✓o 1/4 acre n/a 4b.Location of Well(State Base Plane Coordinates-NAD 27): ,,,� 10.KB Elevation above MSL: 119 feet 15.Distance to Nearest Well Open Surface: x- 99970ii" y .41439#5 Zo e t.rc' GL Elevation above MSL: 119 feet to Same Pool: n/a 6-77 q5 7-g c240 77.(U 16.Deviated wells: Kickoff depth: feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: degrees Downhole: 647 - Surface: 500 - 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 9.875 6.625 24 K55 Mod BTC 33 0 0 -' 33 33 11.6 cu ft w20%excess,.trenne e e 5.5 4.5 11.2 HWT-4130 MBT-FJ 150 0 0 • 150 150 15.4 cu fe w/100%excess.Single Y staae conventional 3.78 3.5 7.67 HQ-4130 MBT-FJ 600 0 0 . 600 600 13.6 cu ft w/100%excess.Single stage conventional 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 ND(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth ND(ft): Junk(measured): Casing Length Size Cement Volume MD ND Conductor/Structural Surface Intermediate Production Liner ,.. Perforation Depth MD(ft): Perforation Depth ND(ft): 20. Attachments: Property Plat ❑ BOP Sketch❑ Drilling Program ❑ Time v.Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program ❑ 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 'PAN i"1j 4‘ R 4WN Title R MAAA ' � Signature [ ).cT7 ) Phone,ea (12 9 2t) Date 2 O ��tJ 1 Commission Use Only / Permit to Drill API Number: Permit ee cover letter for other Number: 2-Jo - U /' 50-2/6-- f..2" � - 9 TZ-Date: va lO requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: 2' Other: Ste. a�-�'at.C.l�d 6owd4. /,d et S Q f pyv ve r, Samples req'd: Yes E No❑ Mud log req'd: Yes ❑"No ❑ (L "'T H2S measures: Yes No❑ Directional svy.req'd: Yes ❑ No [�ak 71{,tC iiii4 k - 1,Yt'rc f_t-, u 1✓t 1 A /,2...el./c-3 p-r If 44e_ l .ROVED �' i) BY THE COMMISSION DATE: 7 -•L ' OR1GNAA740 11* Geothermal Resource Group TAPPING THE EARTH'S ENERGY Bill Rickard, PE Bus:(760)341-0186 P.O.Box 11898 Fax:(760)341-9673 Palm Desert,CA 92255 billrickard @grgi.org Akutan Geothermal Project 3 wa- niav-l-L Elbow Well k Program _ \ > � � \\ ) ka [ ka @ j § J \/ - §\) � ) j \ / { \ \) 2 E § )0H 0 2 CU 0 kf c ` ) f ) ® ® % § ( ) { /) ) ) \ _ 2 § _ . > 0) iim 2 - �Eo II/ (A as as u Ce ( \ - A { 0 ) _ co § % a° 2 } ) \ 00_ o 0 « ` k C ) \ f O• Z0 - � �� \ \ s Ct _ \ \§ \/ { » < m 0 CO \ 0 ) tom 2 $ e o@E k§ % t [ §/ � 2co .0@ c S ` _ . " m - _ _ « \ \ %§ t§ Q. \\ cog 2 � § 0� tE \ /\ 266 ® � , 2 0 cn§ / 5 ); o% — E- \m°, / ` � \� \) liq`0 Geolliennal 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 Ail`'k/IL Elbow Weill ' l' r`- j', Drilling Program 1. Build location with cellar and site sump to suit core drilling rig. 2. Move in drilling rig and rig up. Notify AOGCC of rig up. ' 3. Perform a pre-spud safety and operations meeting. 4. Drill 9-7/8" diameter hole to+30 ft from bottom of cellar. Take returns to wellsite reserve pit using cellar pump. 5. Rig up and run 30+ft of 6-5/8" 24 ppf, K55 casing with a Modified Buttress Thread coupling on the top joint. Leave top of conductor(box end) above cellar floor—no more than 6". 6. Cement conductor 6.1.Run tremie pipe and mix and displace cement into the 9-7/8"x 6-5/8" annulus. 6.2.WOC(wait on cement) until surface grab samples are set. 7. Install Thread-on Riser. 7.1.Line up mixing tub on riser via centrifugal pumps and 2"side outlet valve on lower part of riser. 7.2.Install flow line to mud pit via 3" outlet at top of riser. 8. Pick up P rods and core ahead from to+/-150 ft. 8.1.Notify AOGCC and provide an estimate for completing the section, casing,and BOP testing. - 8.2.Follow the mud program while drilling use 8i.9 pound per gallon mud and maintaining 9.0 pH. 8.3.Note lost circulation intervals and immediately report lost circulation to the drilling supervisor. 8.4.Be prepared for artesian flow throughout rotary drilled interval. 8.4.1.If artesian flow occurs, mix weighted mud using CaCI and Barite. 8.4.2.If weighting mud is insufficient to kill the well, mix neat cement and spot cement across zone. 8.5.Collect and box 10 foot core samples as per geologist's instructions. 8.6.Run a drift shot with MRT at 100 foot intervals. 9. Run and cement HWT core casing to surface. 9.1.Circulate and condition hole for casing. 9.2.POH & lay down P core rods. 9.3.Run and cement HWT(4-1/2"OD)core casing to surface. 9.3.1.Install float above 10'shoe joint. 9.3.2.Make up landing joint. Land casing as needed to set top of HWT core casing 1 foot above bottom of cellar. 9.3.3.Cement using 100%excess as per cementing program.Take returns through 2"side outlet on riser. Displace cement and bump plug. 9.3.4.Take returns through 2"side outlet on riser. 9.3.5.Back-flush cement out of riser bottom through 2"side. 9.3.6.WOC 10. Back off landing joint and pull riser. Clean up threads on riser. Perform top job, if needed. 11. Make up wellhead assembly. 11.1. Thread on 4" 900 wellhead. 11.2. Nipple up 4"900 x 7-1/16"3M DSA. 11.3. Nipple up 6"900 master valve,7-1/16" 3MM annular preventer, 1" kill line valve,3-1/8" manual gate valve,3-1/8" diverter HCR valve, kill and diverter lines. 11.4. Function test annular preventer, kill line,and diverter line valves. 12. Test BOPE to 750 psi. 12.1. Test casing, kill line,and diverter line valves to 750 psi. 12.2. RIH with test plug joint,snub bottom of joint to bottom of annular and test annular preventer to 750 psi. 12.3. While drilling HQ hole,the BOPE must be tested weekly subsequent to the first test. Test the BOPE by landing test plug in crossover and using flared PQ test joint. 13. Pick up HQ rods and wireline core from to+/-600 ft. • 13.1. Perform formation integrity test. 13.1.1. Drill out float and shoe track and clean out cement. 13.1.2. Drill ahead makinj20,feet of new hole. 13.1.3. Apply surface pressure to annulus to an equivalent 0.625 psi(12.0 ppg)gradient. 13.1.3.1. Apply pressure at 0.1 bbl/1 minute increments. 13.2. Notify AOGCC and provide an estimate for completing the section, casing,and BOP testing. 13.3. Follow the mud program while drilling. 2 13.4. Monitor flowline temperatures constantly. 13.5. Note lost circulation intervals and immediately report lost circulation to the drilling supervisor. Maintain water on the backside to prevent flashing. 13.6. Be prepared for artesian flow throughout rotary drilled interval. 13.6.1. If artesian flow occurs, mix weighted mud using CaCI and Barite. 13.6.2. If weighting mud is insufficient to kill the well, mix neat cement and spot cement across zone. 13.7. Collect and box 10 foot core samples as per geologist's instructions. 13.8. Run a drift shot and MRT at 100 foot intervals. 14. Run and cement HQ(3-1/2") core casing to surface. 14.1. Circulate and condition hole for casing. 14.2. POH & lay down P core rods. 14.3. Run and cement HQ core rods. 14.3.1. Install float above 10'shoe joint. 14.3.2. Make up landing joint. Land casing as needed to set top of HQ core below wellhead flange. 14.3.3. Cement using 100%excess as per cementing program.Take returns through diverter liner. Displace cement and bump plug. 14.3.4. Back-flush cement out of wellhead riser bottom through diverter line. 14.3.5. WOC 15. Back off of landing joint and nipple down wellhead assembly. 15.1. If a top job is needed, break off the thread-on wellhead and make landing joint back up. Mix a non-accelerated tail slurry and pour slowly down one side of the annulus,allowing any mud or contaminated cement to exit the other side. Once results are achieved, break off the landing joint and make the thread on wellhead back up. 16. Make up the wellhead assembly and function test the annular preventer and side outlet valves. 17. Test BOPE to 750 psi. 17.1. Test casing, kill line, and diverter line valves to 750 psi. 17.2. RIH with test plug joint,snub bottom of joint to bottom of annular and test annular preventer to 750 psi. 17.3. While drilling NQ hole,the BOPE must be tested weekly subsequent to the first test. Test the BOPE by landing test plug in crossover and using flared PQ test joint. 18. Make up NQ rods and wireline core+/-1500 ft. • 18.1. Perform formation integrity test. 3 18.1.1. Drill out float and shoe track and clean out cement. 18.1.2. Drill ahead making,,c0 feet of new hole. 18.1.3. Apply surface pressure to annulus up to an equivalent 0.625 psi(12.0 ppg)gradient. 18.1.3.1. Apply pressure at 0.1 bbl/1 minute increments. 18.2. Follow the mud program while drilling. 18.3. Monitor flowline temperatures constantly. 18.4. Note lost circulation intervals and immediately report lost circulation to the drilling supervisor. Maintain water on the backside to prevent flashing. 18.5. Be prepared for artesian flow throughout rotary drilled interval. 18.5.1. If artesian flow occurs, mix weighted mud using CaCI and Barite. 18.5.2. If weighting mud is insufficient to kill the well, mix neat cement and spot cement across zone. 18.6. Collect and box 10 foot core samples as per geologist's instructions. , 18.7. Run a drift shot and MRT at 100 foot intervals. . 18.8. If bottom hole temperatures in excess ofd deg F are encountered, it will be necessary to cement the NQ rod in place and reduce to BQ. 18.9. If torque or wellbore stability becomes a problem, reduce to BQ. 19. Upon reaching TD,follow Pressure/Temperature Logging Procedure. 20. Run tubing into well and hang from the wellhead. 20.1. RIH with tubing to near bottom. 20.2. Make up a landing joint and hang the tubing in the mast. 20.3. Kill the well thoroughly using cool water or weighted mud. 20.4. Unbolt the crossover from the wellhead and lift to get access to the tubing joint. 20.5. Slip a spade plate underneath the tubing collar and land tubing on the plate. Back off landing joint. 20.6. Make up tubing hanger flange and land on the wellhead flange. 20.7. Nipple up the flanges and close the top valve. 21. Release rig. 4 0 Akutan Test Well Project Elbow Well 1 Drawn by A.Bailey.GRGI 5/25/2010—Not To Scale 3M Casing Head Flange with/ 3M Tubing Hanger and 1-'/2" 1000 psi Steam Service Valve 5-'/2" Oversize PQ Core to 150' 4-1/2 HWT 11 .2#/ft 4130 Butt Casing to 150' Burst Pressure — Box Shoulder = 2656 psi \\� �Cti Burst Pressure — Midbody = 6218 psi Collapse Pressure — Midbody = 6560 psi (316 deg F Max temp at shoe) 3.78" HQ Core to 600' 3-1/2" HQ 7.67 #/ft 4130 Butt Casing to 600' ILBurst Pressure — Box Shoulder = 4365 psi ` Burst Pressure — Midbody = 6501 psi Collapse Pressure — Midbody = 5788 psi (421 deg F Max temp at shoe) 1-Y2" 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 T N o , 6-5/8" x 14" riser t 1 > __2 0 0 7-1/16 3M _/ 00 Annular Preventer Lt7 co c cri co \ / r ti N ` l o v > (D 00 T � - 6" 900 Exp. Gate Q Valve w/GT Trim 1 I 2 0 0 fD N X X CD CO W - N W T co III C N < CO I Cellar- 72" Diameter Job Recommendation Akutan Test Well Cementing Materials Test Well#1 Volume Calculations and Slurry Properties 6-S/8"Conductor VOLUMES 9-7/8"X 6-5/8" 33 FT X 0.29247 FT3/FT = 9.652 FT3 X 20% = 11.58 FT3 / Total Gallons 86.6 GALLONS Total 8815 2.06 BBLS 12 BAGS TC GEOLITE+3%CaCl2 6-5/8"Cement Slurry Density: 13.5 lb/gal Yield: 1 h3/BAG Water: 4.16 gal/BAG Slurry Volume: 89.8 GALLONS Slurry Volume: 12.0 FT3 Slurry Volume: 2.1 BBLS Mix Water Required: 49.9 GALLONS 4-1/2"Casing VOLUMES 6-5/8"X4-1/2" 33 FT X 0.0808 FT3/FT = 2.666 FT3 X 0% = 2.67 FT3 5-1/2"X4-1/2" 117 FT X 0.0545 FT3/FT = 6.377 FT3 X 100% = 12.75 FT3 / Total Cubic Feet 15.4 FT3 Total Gallons 115.3 GALLONS Total 001.5 2.75 BBLS 16 BAGS 7C GEOLITE+2%CaCl2 4-1/2"Cement Slurry Density: 13.5 lb/gal Yield: 1 h3/BAG Water. 4.16 pi/BAG Slurry Volume: 119.7 GALLONS Slurry Volume: 16.0 FT3 Slurry Volume: 2.8 BBLS Mix Water Required: 66.6 GALLONS 3-1/2"Coiled Tubing VOLUMES 4-1/2"X 3-1/2" 150 FT X 0.024423 FT3/FT = 3.663 FT3 X 0% = 3.66 FT3 3.780"X 3-1/2" 600 FT X 0.011152 FT3/FT = 6.691 FT3 X 100% = 1 FT3 Total Cubic Feet 17.0 3 Total Gallons .5 GALLONS Total BBLS 3.04 BBLS 18 BAGS TC GEOLITE+defoamer+retarder(%to be determined from lab tests) 3.5"CT Cement Slurry Density: 13.5 lb/gal yield: 1 h3/BAG Water: 4.16 gal/BAG Slurry Volume: 134.7 GALLONS Slurry Volume: 18.0 FT3 Slurry Volume: 3.2 BBLS Mix Water Required: 74.9 GALLONS 2.75" NQ ROD VOLUMES 2.99"X 2.75" 750 FT X 0.007513 FT3/FT = 5.635 FT3 X 0% = 5.63 FT3 2.98"X 2.75" 750 FT X 0.011152 FT3/FT = 8.364 FT3 X 0% = 8.36 FT3 Total Cubic Feet 14.0 FT3 Total Gallons 104.7 GALLONS Total BBLS 2.49 BBLS 14 BAGS TC GEOLITE+defoamer+retarder(%to be determined from lab tests) 2.75"NO Cement Slurry Density: 13.5 lb/gal Yield: 1 h3/BAG Water: 4.16 gal/BAG Slurry Volume: 104.7 GALLONS Slurry Volume: 14.0 FT3 Slurry Volume: 2.5 BBLS Mix Water Required: 58.2 GALLONS Akutan Test Well Project qG k 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 • Yield 2.16 cu ft/sack 9.875 in f r None • Total: 20%Excess /7 - ...,/, 2.06 bbl 111 • 5 sacks cement, 33 ft • 140 lbs silica flour 4 • 14 lbs CaCI, 6.625 in Csg • 56 gallons of water 24.00 IbMft • 33 ft 1 None i":', 2.74 bbl • 4.5" Casing 5.500 in fj`: Premium II 13.5 ppg cement w/30 % Silica Flour and 100%Excess // 2% CaCI 150 ft , .; • 11.144 gallons water/sack 4. • Yield 2.15 cu ft/sack 4.500 in Csg 7. Total: 9.50IbMft /' ;/ • 7 sacks cement 150 ft �.; :� • 200 lbs silica flour f • 13 lbs CaCI /, • 78 gallons of water /;. 3.500 in CT / //,' '1 3.5" Casing 9.65 Ibm/ft j 600 ft Premium II 13.5 ppg cement w/30% Silica Flour and 1 None 0.75% retardant 3.780 in /: i , 2.43 bbl II I • 11.068 gallons water/sack 100%Excess �', l';' • Yield 2.13 cu ft/sack 600 ft ..// Total /' • 6 sacks cement • 170 lbs silica flour '/ i://< • 4.25 lbs retardant (Halad 413 equivalent) • 66 gallons of water BoartLongyear r .4111 Energy Products Group OPERATOR City of Akutan WELL NAME Hot Springs (1,500' TD) LOCATION Akutan, AK SUR. CSG. 6 5/8" Ca)_ 30'; 4'/2" @ 200' INT. CSG. 3 '/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. 9.2* 38-50 <15 Utilize Freshwater Bentonite system to drill su be holes for setting surface casing; Quik Gel/X-Hi-Yield Gel for viscosity and good hole cleaning, Soda Ash for pH 9-10. Note possible artesian flow through this interval; utilize Calcium Chloride and Barite for control as needed. Run and cement 4 '/2" (H rod) casing to 200'. 200'- 8.5-9.0* 32-38 5-15 Mix Gel/polymer coring fluid and continuously 600' core (HQ) from 200' to 750' with HQ rod. Maintain 8-20ppb Bentonite (always add Gel first), with .5-1.0 #11,000 gallons EZ Mud Gold and .5-1.0 ppb Pac LV. Add .5-.75 ppb Soda Ash for pH 9-10. Maintain viscosity at 32-38 sec/qt with fresh Gel, EZ Mud Gold and Polyvis as needed; this will also provide lubricity for coring. TORKease may be utilized for additional lubricity/rod chatter; Desco to thin if needed, and Defoamer if needed. IF artesian conditions are encountered, consider increasing fluid density with Calcium Chloride; if whole mud losses are encountered, keep a fluid level by pumping coring fluid and water down the annulus. At 600', cement 3 '/2" core rod or casing. 600'- 8.5-9.0* 32-38 5-15 Continue coring (NQ) with the Gel/EZ Mud Gold 1,500' system as above, using Pac LV and Polyvis as needed for fluid loss and viscosity. Core ahead to projected TD of 1,500'. At TD, perform any temperature logging, kill the well and run 1 '/2" tubing. REMARKS: I. 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 it0 Geothermal Resource Group TAPPING THE EARTH'S ENERGY Bill Rickard, PE Bus:(760)341-0186 P.O.Box 11898 Fax:(760)341-9673 Palm Desert,CA 92255 billrickard @grgi.org June 13, 2010 Pressure/Temperature Logging Procedure 1. After retrieving the core at hole TD,circulate the hole for a minimum of 1 hour. 1.1.Reciprocate pipe frequently while circulating. 2. Make a wiper trip from TD to the casing shoe. RIH to TD. 3. Circulate and condition hole for logs. 3.1.Carefully note the time at which circulation begins. 3.2.Thin mud back with water to around 8.6 pounds per gallon. 3.2.1.Circulate until the mud properties are the same going in and coming out. 3.2.2. If there is no circulation, pump a full hole volume of 8.6 ppg mud. 3.3.Circulate until a stable flow line temperature has been reached. 3.4.Reciprocate pipe frequently while circulating. 3.5.Carefully note the time at which circulation ends. 4. Pull out of hole. 5. Make up wireline lubricator, FOSV,or stab in with circulating pin. DO NOT CIRCULATE UNLESS NEEDED FOR WELL CONTROL. 6. Prepare Pressure/Temperature tool and synchronize with P/T laptop. 7. Make up 0-650 deg F Pressure/Temperature tool in accordance with PPS logging procedure. Use wireline lubricator during the log run. 8. Begin Log Run#1. This run should begin 6-8 hours after circulation has ended. • 8.1.Note exact time that log run begins, and exact time at each station while running log. 8.2.Run in hole slow, making stops on 20 foot stations. Time on station will be established by PPS engineer. 8.3.Make additional stops at points selected by geologist. 8.4.Do not attempt to force tool past any tight spots. If tools sets down and won't proceed, RIH and clean out tight spots. After cleaning out tight spots, return to Step 3 and repeat the entire process. 9. Download and examine data at end of run. 10. Begin Log Run#2. This log run may begin at any time after completing Log Run#1. 10.1. Note exact time that log run begins, and exact time at each station while running log. 10.2. Stations and time spent on station should be duplicated from Log Run#1 10.3. Do not attempt to force tool past any tight spots. Examine data—if tool sets down below any points of interest,the log run may be considered complete. Otherwise, it may be necessary to clean out hole and repeat from Step 3. Sample Data Sheet Station Log Run 1 Log Run 2 Delta Depth Arrive Depart Time on Time Temp Arrive Depart Time Time Temp Temp Station since Last on since Last Circulated Station Circulated ■ Flow Testing and Sampling 1. After completing Pressure/Temperature Logging to the satisfaction of the wellsite geologist, RIH to bottom with bit. 2. Circulate fresh water down pipe, reciprocating pipe constantly. 2.1.If the well will circulate, circulate fresh water until returns have reached a mud weight of 8.5 or less.I 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 -411_ O C Ts E l O 1- 2 as ca N 0) a> z a U) — • J Q Q Q o r O 5 p ,U c m ,n UO O —U � a) = CD N U I(n Y Cl)t < H~ = C ..-> -. ca 4 o co 7 le 0 �� N Q a 0 E J a) 1— O) O C a) u) as d O zo co m - .Q- I I co _U N C CV (/j p 0 E L 4-- V - a) 0 o co O c 'N r.+ O Q C co � 1 F- co I- a_ N a z = z co- cn a) M _c L a O) O O t C co O O a) Q - °-— E CO —Z 2 ca LI H II Akutan Drilling 2010 Sample Bailer Drawn by A.Bailey,GRGI 5/15/2010—Not To Scale n 1-W Coupling XO to wire rope socket Top Strainer– 1-1/2" X 8" Nipple with holes drilled 1-'/2" Coupling Top 1-'/2" Check Valve – spring cut to reduce plunger pressure 1-'/2" Coupling Sample Chamber– 1 1/2" X 60" Nipple 1-1/2" Coupling Bottom 1-'/2" Check Valve – spring cut to reduce plunger pressure —Bottom Strainer– 1-1/2" X 8" Nipple with holes drilled- 1-'/2" Coupling _Sinker Bar, 1-'/2" Sch 40, 5 feet long and filled with sand. Epoxy plug at top JEnd Cap – Rounded to a Bullnose CITY OF AKUTAN,ALASKA WELLSITE GEOLOGY PROGRAM FOR GEOTHERMAL TEST WELLS Driller's responsibilities The driller's helper will box and label core, and stack the boxes on a pallet. Don't let them skimp on boxes—"one barrel,one box." It is important to emphasize that they let the core drain really well before boxing. Otherwise, the box will be full of polymer. The driller (or helper) will prepare daily drilling logs, core reports, weekly situation reports, serious incident reports, as required, and end of well reports. Rate of penetration and mud returns will be obtained from the driller. The driller will need to log drilling times on his worksheet, and note intervals where there are "drilling breaks". He will also need to note if he is losing (or gaining) fluid. These numbers will be entered manually into the logging software by the wellsite geologist. The driller will take drift measurements at 100 foot intervals while drilling to determine . deviation from true vertical. At the same time, the driller will run an MRT to take bottom hole temperature. The driller will note the MRT reading on his tour report and the geologist will log the bottom hole temperature from the MRT on the mud log. Core Logging Procedures 1. Wipe the slime off the core (polymer and mud, etc.) using a bucket of clean water and sponges/towels. Can use the provided spray nozzle and water hose. But don't get too energetic and scub the core itself away! 2. A box of core will read just like a book—left to right and top to bottom. On each cut of core, put a red line on top of each section and a black line on bottom.This orients each core section relative to top and bottom. 3. Mark a section number—if broken into 12 pieces, mark 1-12. Include any pieces that appear to be ready to fall apart. 4. Do gross description. If need to see a fresh surface, whack w/rock hammer. Note the following: 4.2 Rock Type. 4.3 Color. Use a GSA color chart. 4.4 Texture. 4.5 Hardness and Induration. A trick to determining induration is to hit the core with a hammer. Highly indurated or silicified rock will "ring" and poorly indurated or CITY OF AKUTAN,ALASKA WELLSITE GEOLOGY PROGRAM FOR GEOTHERMAL TEST WELLS argillic altered rock will "thud." Everything in between is more or less a judgment call. 4.6 Fractures, veining, vugs and other physical features. Use a protractor for a rough angle. 4.7 Hydrothermal alteration. Describe suite (argillic, propylitic, etc.) 4.8 Hydrothermal mineralization. 4.9 Contact or contact zone, and whatever length interval it's over(use a tape measure) 5. Fill out placard with the following information: 5.2 Core Box Number; 5.3 Depth from and to; 5.4 Estimated Percent of Recovery. (I print out batches of these on blank 3x5 index cards and fill in the blanks.) After taking the photo,tuck the card underneath a piece of the core. This will help to identify the core if the lid to the box should be lost. 6. Take a high-resolution digital photo of the core box: 6.2 Pay attention to color. Be consistent—always photo either in natural light (set light balance) or copper photo lights—don't try to photograph in incandescent light. Run an egg timer and set it for an hour, set light balance over course of the day. Photograph in oblique light so no glare. Kodak color separation chart. Set white balance. 6.3 Make sure it's from the same fixed distance each time (use tripod w/piece of string to measure distance) 6.4 Include placard as well as core box 6.5 Photograph anything else significant. 6.6 Photograph the chart each time the white balance is reset and try to include the color chart in each photograph. 7. Transpose descriptive data from worksheet into LogPlot 8. Enter other data (rate of penetration, PT info, circulation information, etc... into LogPlot. 9. Maintain a 10 foot sample chip set for Alaska Oil and Gas. CITY OF AKUTAN,ALASKA WELLSITE GEOLOGY PROGRAM FOR GEOTHERMAL TEST WELLS Supplies: Core Logging - Bucket of clean water - Sponges and towels - Water hose w/spray nozzle - Black and red permanent markers - GSA color chart - Rock hammer - Hand lens and/or magnifying glass - Blank index cards - Pre-printed index cards("placards") w/info given above - Digital camera and tripod - Kodak color index - Egg timer - Copper photo lights? - Laptop w/ LogPlot software CITY OF AKUTAN,ALASKA WELLSITE GEOLOGY PROGRAM FOR GEOTHERMAL TEST WELLS Akutan Test Well Project Fo,N*e 7HepeleaYe14e00F0e1 IN•vn by A.blot ERC1.1.5171 41- /- USB DATA RECORDER —Type T,J a K Therm000uple- -%"Thermanetl-Threaded- _ 34'Coupling Schematic of Flow Line Data Recorder O a U N a) 0 C a) E - O J (, H N W F- J CQ cc Q Y = Q 0 J W Q Z N Q 0 H 2 Q • ce s O O U H a r U >- l7 Q C W 0 a Q N U J Cr CU C. O O C. c E 0 Akutan Account Codes 99.01 Mob/Demob 99.02 Rig Footage 99.03 Rig Hourly 99.04 Rig and Camp Fuel 99.05 Location Cost 99.06 Communications 99.07 Camp Services 99.11 Drilling Supervision 99.12 Drilling Engineering 99.13 Geology 99.14 Logistics 99.15 Roustabouts 99.16 Travel Expense 99.17 Vehicles 99.21 Helicopter Daily 99.22 Helicopter Fly Time 99.23 Helicopter Fuel 99.31 Conductor& Casing 99.32 Cement 99.33 Bits & Tools 99.34 Drilling Fluids 99.35 BOPE 99.36 Wellhead & Tubing 99.37 Small Parts & Supplies 99.41 Rental Equipment 99.42 Drift & Directional Tools 99.43 Logging & Well Testing 99.44 Other Services 99.45 Shipping rEplacEmEnt parts industriEs, inc. I•p CALL 800-221 -9723 or 818-882-8611 • FAX 818-882-7028 E-MAIL: techsupport @rpiparts.com • WEBSITE: www.rpiparts.com 'The Alternate Source" RPT 113 MAXIMUM REGISTERING THERMOMETER INSTRUCTIONS This thermometer registers the highest temperature it has been exposed to and holds that temperature indi- cation until reset. This feature works on the principle of a constricted capillary; on heating, the expansion of the mercury within the bulb forces the mercury col- I _ f umn through the constriction. The constriction pre- vents the mercury column from retreating under the influence of gravity or mild vibration. Retraction of READ COLUMN the column is accomplished by `shaking' the ther- HERE FOR MAXI- mometer, much like one would a fever thermometer, MUM TEMPERA- thus generating centrifugal force and forcing the mer- TURE —* cury column back through the constriction. Do not be concerned about the apparent separation of the mercury column below the constriction. This is a normal condition while the indication is above ambi- ent temperature, and will not affect the accuracy of the indication. The mercury will rejoin after shaking down to ambient temperature. IMPORTANT: The thermometer should be reset prior to each use as described above. Be sure to continue shaking until the column registers approximately ambient room temperature. Place the thermometer into the environment you wish to measure. The ther- mometer should be allowed to remain exposed to the temperature you wish to measure for at least five min- utes, and ALLOWED TO COOL TO AMBIENT TEM- PERATURE BEFORE IT IS READ. READ IN AN DO NOT BE CON- UPRIGHT POSITION AND ONLY AFTER IT HAS CERNEDA COOLED TO AMBIENT TEMPERATURE OR YOU SEPARATIONS ABOUT HERE WILL OBTAIN A FALSELY HIGH READING. __110-O REV (3/00) Conditions of Approval City of Akutan North Elbow Well 3 (PTD 210-072) 1. Well operations shall be conducted in accordance with 20 AAC 25. 2. Pursuant to 20 AAC 25.035 (h) (1), alternate BOPE is approved. 3. Pursuant to 20 AAC 25.035 (h) (2), the diverter requirement is waived. 4. Pursuant to 20 AAC 25.061 (c), the near surface survey requirement is waived. 5. Pursuant to 20 AAC 25.066 (d) (3), alternate gas detection equipment is ap- proved. At least one methane detector and one H2S detector are required. 6. Test BOPE to 750 psi on a seven-day frequency. �� j ; ---r O ` r - � ■ N N C 1 *Ay i t.,-;. :. fi-:,- ,.,, , i ,, .... ..... wilik „ . , I! ._ 0g RI LL i , t . �a - a, °o c`1 l i u .,, •,,V.z.___ ---...... 1))/ (iii a- 0 (/ E m V - J { ,., .. , ......___ Z 1 ,,. tl . )), (N1 esi • /ft .r O C CI 0 j 1 N. _ 0 Qa I / }� ,■ ;, o :--!r-.y 'i I N Ni Z Z I I I //,-;:„. 1 j Q ui ai I;\, 1 0' , 9 W _ N ^ N N )Vj � __-,, / co O N P" ( a s -- -j J '1� ,i \ jjj -^.- I �� t.•4 y 2 u�1 N eY1 II II M1 .�. Il it — X } N �J� f1 1 m 1 3 t11 N IA i%r-_- �1�\Vtii-). 3 x O II II ' a `� t W LL LA. 41 `rr } J3 ` `\� :\---.. -- _ '_-�_ }1 !rte ■ � � LJJ LL LL ,` '•r+^r� _ -_' ° O l"1 t0 f CL -1 ' ' ../ 'it:ilf.',- I . * , .,,, . .\-\,,,k,„:1.„. _,,,,,–.\--1-\\...% CD '� ,.. /liar( 1 ' % o ? . ' --, . ,t� �. _ qt i tom' r 11e -7- 4J J -..1 _ Q) i1' _! ,/e.1 LL LL �`•� �- ( 1 `..1.1 l ._,,_ Jef ^2' (7 00 n ,:1 f am/t./ 4r ^� — . �. c / ' ! ! + /./:"eje. 0 0 p :"rT''..t A j,/,---. 1‘..,. i N N p 0 O ` Q_ G) W a) 0 D ao N o AOGCC North Elbow Well 3 1 July 2010 INPUT OUTPUT Geographic,NAD83 State Plane,NAD27 5008-Alaska 8,U.S.Feet Accuracies of conversions from NAD 83 to NAD 27 am typically 12 to 18 cm. North Elbow Well 3 1/1 Latitude: 54.14333 Northing/Y: 52678.096 Longitude: 165.87390 EastinglX: 527456.868 Convergence: 0 06 13.68776 Scale Factor: 0.999900859 Datum Shift(m.): Delta Lat.=96.650,Delta Lon=-128.913 aee i,;c &.1-.).1)1114 . �� k'//Zld1 5/11. r=13' 2 ck i(,Ah z7 AA„,i ihs 5 z‘-'77, 55 E[ , =J 7E='a 12ttZ1. .�vt. 7// Remark: NAD 83 lat/long conversion to ASP Zone 8 NAD 27 Corpscon v6.0.1,U.S.Army Corps of Engineers Davies, Stephen F (DOA) From: Robert Kirkman [REKirkman @rmabs.com] Sent: Thursday, July 01, 2010 9:38 AM To: Davies, Stephen F (DOA) Cc: raymann @rmabs.com Subject: RE: Coordinates Needed Attachments: GeothermalVicinityMapUpdate2_lowres (2).pdf Hi Steve, Coordinates as requested projected in Lat/Long: Well 4 N 54.13753 W 165.87828 Well 3 N 54.14333 W165.87390 - I did not come up with any difference when I reset the coordinate reference from NAD 83 To WGS 84. The main difference is between NAD 27 and NAD 83/WGS 84. I attached a geospatial map with the wells located on it. If you download a free copy of terra tools, you can obtain dynamic lat/long readings when you pan across the map. Call if you have any questions. Bob Robert Kirkman Technical Services Manager RMA Consulting Group 221 E. 7th Avenue, No. 101B Anchorage, AK 99501 (360) 259 9570 --representing-- City of Akutan 3380 C Street, Suite 205 Anchorage, AK 99503-3952 From: Davies, Stephen F (DOA) [mailto:steve.davies @alaska.gov] Sent: Wednesday, June 30, 2010 4:15 PM To: REKirkman @rmabs.com Subject: Coordinates Needed Bob, 1 Thanks for your help. I could use the lat/long coordinates for North Elbow Well 3 and South Elbow Well 4 referenced to both WGS 84 and NAD 83 if possible. With two separate coordinate systems, I'm sure that I can make the conversion I need and likely won't have to bug you again. Steve Davies Sr. Petroleum Geologist AOGCC 907-793-1224 2 TRANSMITTAL LETTER CHECKLIST WELL NAME /ti‘r 14- .61, &&) GLIB l( 3 PTD# Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: 9464//-/1 POOL: alz )/t a1--4efitwie 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 Al! 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 obta'n advance approval of such water well testing program. ( ,4e4 F Rev: 1/ 1/2008 C z4b 7t, /6 /Q `- u a) R Cu N N Cu N 0 3 O '`u (I) L 7 (p > ' ■ , , ,Q a , ' 5. ; ; ; £, m ar t. 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