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C c U E o O E �, E E a• 0 O a 0 I O) o f ci C • • Release of Confidential Data Coversheet Well Name: OLSON CREEK 2 PTD: 214-113 E-Set:T24947,T25320,T25331,T25332 ✓ Physical data labeled with PTD, E-Set# Conf. entry: various ✓ Import CD data to RBDMS ✓ Confidential (incomplete) entry in Well Data List notes 2// Import to DigLogs via E-Set tab IH1 Scan labeled data R1 Apply OCR text recognition //Save to Well Log Header Scans ✓ New"complete" entry in Well Data List notes Logged by: Meredith Guhl Fully logged: 12/2/2016 • Guhl, Meredith D (DOA) From: Decker, Paul L(DNR) Sent: Wednesday, October 19, 2016 10:58 AM To: Guhl, Meredith D (DOA) Cc: Bettis, Patricia K (DOA); Davies, Stephen F (DOA); Hyun,James J (DNR) Subject: RE: Olson Creek 2, PTD 214-113, Extended Confidentiality? Hi Meredith, DNR has not received a request for extended confidentiality on Olson Creek 2, PTD 214-113. Thanks, -Paul Paul L.Decker,Petroleum Geologist Resource Evaluation Manager Alaska Division of Oil&Gas 550 W.7th Ave,Ste.1100 Anchorage,AK 99501 (907)269-8791 paul.decker@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Department of Natural Resources(DNR),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the DNR is aware of the mistake in sending it to you,contact Paul Decker at(907) 269-8791 or paul.decker@alaska.gov. From:Guhl, Meredith D (DOA) Sent:Wednesday,October 19, 2016 10:25 AM To: Decker, Paul L(DNR)<paul.decker@alaska.gov> Cc: Bettis, Patricia K(DOA)<patricia.bettis@alaska.gov>; Davies, Stephen F(DOA) <steve.davies@alaska.gov> Subject:Olson Creek 2, PTD 214-113, Extended Confidentiality? Hello Paul, Has Cook Inlet Energy requested extended confidentiality for Olson Creek 2, PTD 214-113, due for release on November 5, 2016? Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W.7th Ave,Anchorage,AK 99501 meredith.guhl@alaska.gov Direct: (907)793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, 1 please delete it,without first saving or forti7L�l�fing it,and,so that the AOGCC is aware of the mista'l�fn sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 2 _ Cook Inlet Energy_ June 17th. 2015 Mr. Gu Schwartz Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Re: Olson#2 Well Completion Cook Inlet Energy, LLC: Olson Creek#2 Permit to Drill No: 214-113 Dear Mr. Schwartz, Please find our enclosed additional information requrested to for our 10-407 Well Completion submittal for the Olson Creek#2 well. Included are: • updated daily summary • recorded flow information while attempting to bring the well on • pictures of the well abandonment cap and pad. If you have any questions,please contact me at(907)-727-7404. Sincerely, RECEIVED JUN 17 2015 Conrad Perry AOGCC Drilling Manager—Cook Inlet Energy 601 W.5"'Avenue,Suite 310,Anchorage,AK 99501 (907)334-6745*(907)334-6735 fax • • Olson Creek 2 Drilling Summaries PTD: 214:113 8-8-14-8-27-14 Rig move, site prep, rig up diverter. 8-28-14 SPUD. Drilled ahead to 372'. 8-29-14 Drill ahead from 372'-1581'. 8-30-14 Drilled ahead from 1581'-2023'. Condition mud and circulate hole clean. Back ream out of hole to 190'. RIH to bottom. Circulated hole clean. POH. LD BHA. 8-31-14 RU to run casing. Pick up shoe track,test floats. Run 9 5/8" 47# P110 BTC casing to 2,023'. Head up casing and circulate. CEMENT CASING: PUMP 5 BBLS WATER, KICK OUT BOTTOM PLUG. TEST LINES TO 3000 PSI. PUMP 33 BBLS SEALBOND SPACER @10 PPG. MIX & PUMP 198 BBLS, 525 SX. LEAD CEMENT, YIELD 3.13, MIX H2O 12.02 GAL/SX, AT 12.5 PPG. MIX & PUMP 59 BBLS, 260 SX. TAIL CEMENT, YIELD 1.27, MIX H2O 5.72 GAL/SX, AT 15.2 PPG. KICK OUT TOP PLUG, AND DISPLACE WITH 148 BBLS 9 5 #/GAL MUD. AT 2.5 BPM, FCP=640 PSI, BUMP PLUG 500 OVER AT 1140 PSI. BLEED BACK 2.5 BBLS.FLOATS HELD. 49 BBLS CEMENT TO SURFACE. CIP@ 13:30. WOC. Flush cement unit. Nipple down annual diverter. 9-1-14 Nipple down diverter system. Install 11x5K multibowl wellhead. NU BOPE. Stack rams. Cont NU. 9-2-14 Continue NU. Start BOPE test 9-3-14 Cont BOPE test. PU BHA. Drill out shoetrack. Perform FIT to 15.06ppg EMW. Drill ahead to 2215'. 9-4-14 Drill ahead from 2215'-3641'. 9-5-14 Drill ahead from 3641-4637'. Short trip to 3,181'. Circulated. RIH to bottom. Drill ahead to 4879'. . • • 9-6-14 Drill ahead from 4879-6019'. CBU. POH to 5550'. CBU. POH to 5070'. 9-7-14 POH to 4631'. CBU. PU singles and start running in the hole. Drill ahead from 6019'- 6820'. 9-8-14 Drill ahead from 6820'-7543'. POH. 9-9-14 Cont POH for BOPE test.Test BOPE. 9-10-14 CBU. POH. PU new BHA. PJSM. MWD test. RIH with BHA#3. CBUx2 at shoe. RIH. Shut in well and CBU through choke as a precaution. Check flow. Drill from 7543'-7731'. 9-11-14 Drill ahead from 7731'-8480'. CBU.TD for 8.5" hole. POH. 9-12-14 POH. 9-13-14 Finish POH. Pull wear bushing and set test plug. Test 7" BOPE. RU Weatherford for casing run. PJSM. PU shoe track. 9-14-14 RIH with casing to bottom at 8480'. Circulate hole clean. 9-15-14 PJSM with cementers. RU for cement. Baker pump 2bbls water and pressure test lines T/3000psi. Drop plug, build and pump 10.5ppg 40 bbl spacer. Pump 66 bbls of 15.8ppg class G cement(yield = 1.15, Gal/sk=4.93, 370 cuft.) reciprocating casing while pumping, displace with 315.8 bbls, Bumped plug. Checked floats, Cement in place at 03:38. Rig down landing joint. Drain and wash out stack. Land pack off and test void to 5000. Rig down casing tools. RD and LD tools. 9-16-14 LD 5". PU test plug. Test BOPE. 9-17-14 RIH. 9-18-14 0 • RIH. Drill out shoe track. From 8,392'-8,480'. Drill ahead from 8,480'-8,763' 9-19-14 Drill ahead from 8,763'-8,911'. 9-20-14 Drill ahead from 8,911'-9,338'. 9-21-14 Drill ahead from 9,338'-9,880' 9-22-14 Drill ahead from 9,880'-10,414' 9-23-14 Drill ahead from 10,414'-10,849' 9-24-14 Drill ahead from 10,849'-11,504' 9-25-14 Drill ahead from 11,504'-11,589' and TD the well. POH 9-26-14 BOPE test. RIH with cement retainer at 8,410'. Pressure tested casing. 9-27-14 PJSM. Cement casing with 10 Bbls ahead of water followed by 9 Bbls cement, 44 sx, yeild 1.15, H2O GPS 4.91, @15.8 PPG. Displace cement with 88 Bbls of mud. Squeeze away 5 Bbls water, 6 Bbls cement, unsting and drop 3 Bbls cement on top of retainer. CIP@4:30. Maintained 900 PSI on annulus while displacing cement. RD cementers. POH. RU wireline. Run CBL. POH. PU 7" Casing scraper assy. 9-28-14 RIH with assy to 8,310'. Pump downhole, 50bbl hi-vis pill. Displace well with 3% KCL brine. Circulate. 9-29-14 Circulate and filter brine 9-30-14 Finish filtering. POH. LD tools. PJSM. RIH with perf assy to 7,584'. RU wireline. 10-1-14 Correlate and space out perf assy. Set packer. Pressure tested lines. Drooped bar. Flow tested well. • 10-2-14 Flow tested well. 10-3-14 Flow tested well. POH to 5,155'. 10-4-14 POH for BOPE test. BOPE test. PJSM. PU retainer BHA. Sheared out of retainer at 35K over pickup.Verify set. Begin pressure testing Drill Pipe. 10-5-14 Pressure tested drill pipe. Pressure tested casing. Squeezed 10.7 bbls of cement below retainer. Unstung and placed 5 bbls of cement on top of the retainer. Pulled to 7,000' and circulated at 690 gpm, 3,968 psi. Saw trace cement returns to surface. LD drill string to 1,000'. RIH to 5,200'. Mixed and pumped 30 bbl Hi-Vis Pill. POH. LD 4" DP. Ru and tested casing and bottom cement plug to 2,500' PSI for 30 minutes. 10-6-14 Set bridge plug at 310' and tested to 2500 psi for 30 minutes. Punched 8 holes in 7" casing at 301'. Rigged up cementers and pumped 27 bbls 15.8 ppg cement down casing. Had returns after 21 bbls. Washed out top 5' of cement from wellhead flange. Tested cement plug to 700 psi for 30minutes. Observed 200 psi drop, but no returns up annulus. 10-7-14 RIH with drill pipe tagging cement inside 7" at 42'. Pump 5 bbls 15.8 cement with 3.5 bbls returns to cellar. Pump 1/4 bbl cement down 7" x 9 5/8" annulus. WOC. Test 7" to 1500 psi, 9 5/8" to 1500 psi for 30 minutes - good test. 10-8-14 to 10-17-14 Rig Move off location 10-18-14 Remove wellhead and cellar. 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',. .i , ii dl 1 ! 1.. � 4 7 �G,i ,4° , 'S J tA.« . d 7 ,d A , , I P p `' 1 i {- 1,14. ,41i 11, * , . f. a , M1 ` ,* I 4 � ! 4 t, " t 4 ` 4 T2 .xa. - .1 } a ,t . 4. R S +,I ir1 " 1;1, 1. d r I 1, 4 . • • Davies, Stephen F (DOA) From: Conrad Perry <Conrad.Perry@cookinlet.net> Sent: Wednesday,June 17, 2015 1:55 PM To: Schwartz, Guy L(DOA) Cc: Stephen Ratcliff; Sarah Gallagher; Field Superintendant Subject: RE: Olson Crk#2 (PTD 214-113) Attachments: Olson Creek 214-113 Summaries rev l.docx; CIE Olson Creek 2 093014.xlsx; Olson #2 Well Stub Pic 2 jpg; Olson#2 Well Stub Pic 3 jpg; Olson#2 Well Stub Pic jpg; Olson Creek Pad_10-20-2014_002.jpg; Olson Creek Pad_10-20-2014_003 jpg; Olson Creek#2 _Abandonment_10-20-2014_002 jpg; Olson Creek Pad_10-20-2014_001jpg; Olson Creek#2_Abandonment_10-20-2014_001 jpg Guy, Please find attached the documentation you are looking for. I have updated the daily summaries through the welding of the abandonment cap and included pics of the same. I have included a spreadsheet kept by PTS while we were trying to get the well to "come on". It flowed at a high water rate with minor entrained gas that was too small to measure. PTS concluded that the line heater consumed 500 scf/hr and used that as an estimated rate. I am preparing a cover letter and copies of the above for your files. conrad From:Schwartz, Guy L(DOA) [mailto:guy.schwartzc 1alaska.gov] Sent:Tuesday,June 16, 2015 4:17 PM To: Conrad Perry Subject: Olson Crk#2 (PTD 214-113) Conrad, I was looking at the 10-407 for Olson Crk. #2. It is missing some items: 1) The operations don't go past Oct 5th. Missing a few days about P &A operations. 2) No pictures of the P &A cap or welded plate. 3) NO data about the well test. 4) Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). 1 ' ,..t...... i 'vr.:••- .C...71.. ' ...-... ' , '''''i. : .; . • k-•.','.-7r•I''.7-.... 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" Hut-. * 4.z �✓t r �t� 01,,v z_ Regg, James B (DOA) ),14 ( ' From: Regg,James B (DOA) Sent: Wednesday, June 15, 2016 3:07 PM 14.4 f'/ 5L To: 'Conrad Perry' Subject: RE: Olson/otter Pictures are sufficient; we will not require a separate location inspection. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: Conrad Perry [mailto:cperry©glacieroil.com] Sent: Wednesday, June 15, 2016 2:17 PM To: Regg, James B (DOA) Subject: Olson/otter Jim, Were those pics sufficient? conrad SVP - Drilling GLACita Glacier Oil and Gas Corporation 601 W. 5th Avenue STE 310 Anchorage, AK 99501 (907) 727-7404-Cell (907) 344-0584- Home (907) 260-5356—Cabin cperry@glacieroil.com CONFIDENTIALITY NOTICE:This e-mail transmission and any document,files or previous e-mail messages attached to it,are confidential. If you are not the intended recipient,or a person responsible for delivering it to the intended recipient,you are hereby notified that any review,disclosure, copying,dissemination,distribution or use of any of the information contained in,or attached to this e-mail transmission is STRICTLY PROHIBITED. If you have received this transmission in error,please notify us immediately by forwarding this message to the original sender or by telephone at 907.433.3816 and then delete this message and its attachments from your computer. 1 • • cel so Cr'e z Regg, James B (DOA) 1c -50 From: Conrad Perry <cperry@glacieroil.com> Sent: Wednesday, June 15, 2016 9:39 AM To: Regg,James B (DOA) Subject: Olson Creek Attachments: IMG_2104jpg;IMG_2105 jpg;IMG_2103.jpg Jim, Here are some better pics of the Olson Creek#1 pad. conrad SVP- Drilling Glacier Oil and Gas Corporation 601 W. 5th Avenue STE 310 Anchorage, AK 99501 (907) 727-7404-Cell (907) 344-0584- Home (907) 260-5356—Cabin cperry@glacieroil.com CONFIDENTIALITY NOTICE:This e-mail transmission and any document,files or previous e-mail messages attached to it,are confidential. If you are not the intended recipient,or a person responsible for delivering it to the intended recipient,you are hereby notified that any review,disclosure, copying,dissemination,distribution or use of any of the information contained in,or attached to this e-mail transmission is STRICTLY PROHIBITED. If you have received this transmission in error,please notify us immediately by forwarding this message to the original sender or by telephone at 907.433.3816 and then delete this message and its attachments from your computer. 1 0 • Location Clearance—Olson Creek Drillsite Olson Creek#1 (PTD 2121710) Olson Creek#2 (PTD 2141130) Photos courtesy of Cook Inlet Energy 6/15/2016 i ' . • rF x ►� L r kt 1 ` 1 X "* 2016-0615_Location_Clearance_OlsonCkphotos.docx Page 1 of 2 • 0 - f. fi ,. ,. aVF 4 1 r•.. a x ,ti '., w Z;. 14 2016-0615_Location_Clearance_OlsonCkphotos.docx Page 2 of 2 • OCSoi al'ek- z- Zt41(3o Regg, James B (DOA) From: Regg,James B (DOA) Sent: Wednesday,June 15, 2016 9:10 AM (,(E5( 1„, To: 'Conrad Perry' Subject: RE: Olson #1 and Otter 1A Inspector did witness the surface abandonment but I don't have any record/indication of the visual inspection of the wellsites to meet our location clearance requirements. Reference 20 AAC 25.170. Photos to document the condition of the two wellsites are acceptable in lieu an inspection in this case. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: Conrad Perry [mailto:cperry@glacieroil.com] Sent: Wednesday, June 15, 2016 8:49 AM To: Regg, James B (DOA) Cc: Stephen Ratcliff Subject: Olson #1 and Otter 1A Jim, Could you please send me the abandonment inspection sheets for these two wells for our files. I can't remember, do you do a final "approved" abandonment letter. We would like to inform Mental Health Trust and DNR that we have met the abandonment requirement to release our bond. Thanks, conrad SVP- Drilling Glacier Oil and Gas Corporation 601 W. 5th Avenue STE 310 Anchorage,AK 99501 (907) 727-7404-Cell (907) 344-0584- Home (907) 260-5356—Cabin cperry@glacieroil.corn 1 • 214113 Cook Inlet Energy, LLC 2 5 3 3 1 601 W. 5th Avenue, Suite 310 1 5 3 3 2 Anchorage, Alaska 99501 DATA LOGGED Phone: (907) 334-6745 Fax: (907) 334-6735 t las/2015 K. BENDER DATA TRANSMITTAL Date: January 27, 2015 To: Meredith Guhl From: Barbara Kruk AOGCC Cook Inlet Energy, LLC 333 W. 7th Ave, Suite 100 601 W. 5th Avenue, Suite 310 Anchorage, AK 99501 Anchorage, AK 99501 Phone: (907) 279-1433 Phone: (907)433 - 3802 FAX: (907) 334 -6735 NO LONGER TRANSMITTAL DESCRIPTION CONFIDENTIAL Well Data for Olson Creek #2, API#50-283-20174-00-00 NOV 0 5 2016 In accordance with Alaska Regulations 20 AAC25.537(b), we request that confidentiality be extended to all of the following information. Item Qty Description 1 1 Paper Copy- Lat/Long Coodinates for Surface & Bottom Hole Locations - 1 page 2 1 Paper Copy- List of Formations and other Geologic Markers Encountered - 1 page 3 1 Paper Copy- List of logs run and depths covered by each log - 1 page 4 1 Paper Copy- List of Oil & Gas Shows - 1 page 5 1 Paper Copy- List of Abnormal Pressure Zones - 1 page 6 1 CD - Olson Creek-2; Date 1/27/15; 5 files; 45 KB Lat/Long Coordinates for Surface and Bottom Hole - 1file List of formations and other geologic markers encountered - 1 file List of logs run and depths covered by each log - 1 file List of Oil & Gas Shows - 1 file List of Abnormal Pressure Zones - 1 file 1 Printout of above listed CD - 1 page 7 1 Paper copy of final well report for Olson Creek-2 (Canrig) Binder CD enclosed in Report for Digital copy of Final Well Report& Mudlogs (59 files; 226MB) Paper Copy of Mudlogs - Olson Creek-2 - Enclosed in Canrig Well Report Binder Olson Creek-2 - Formation Log MD &TVD; Gas Ratio Log MD &TVD Olson Creek-2 - LWD Combo Log MD &TVD; Drilling Dynamics Log MD &TVD Digital copy on CD for all mudlogs tr Us !!P!'4! Please sign below to acknowleceipt. i n JAN 2 Received By: Date: Angela K Ctngh AOGC(,- Returned to Cook Inlet Energy, LLC Date Accepted By: Transmittals CIE AOGCC.xlsx/AOGCC 1 27 14 OlsonCrk2 • • RECEIVED JAN-2 7 2015 _ Cook Inlet Energy_ AQGCC r 1�� Cook Inlet Energy Olson Creek #2 8/28/14 - 9/25/14 Section 6 — T13N - R10W, SM Upper Cook Inlet, Alaska FINAL WELL REPORT Lees Browne Jr — Senior Logging Advisor George Baker — Senior Logging Geologist CANRIG DRILLING TECHNOLOGY L.TD. • • i _ Cook Inlet Energy_ i' Olson C '.' '`' 2 I r. I T Contents: ' Daily Reports DML Data ,.„- Final Well Report Sept 25, 2014 LAS Files ; ... Log PDF Files i e' \ Log TIFF Files z 1c ., e vat We ata ,, F1 1 I .r err_, _ t.*wx CANRIG _ • , • • --_- -- ,.-,, Djvieri - emet%11.01.4_,. il 111211W__ , , CD-R 1, Ir \ \ 1 , 1/4. 1 \ v,piteeelsse Re ord..> rt6011 i • = . min I ' CA Otle) trintA4 -'--2P---- I . ionia • 50 Aft a 0,3.. 0114 40 1.- • MI .LO 1.)Cr4eitiS.- 1116414SC 1, 1' S‘VNA___641.C6 , 5 filE ,,,,, ,. .. , , .. ., S ------'2 - m 4 a A. Ili III aogcc_olsonck2_1-27-15_cdl.txt volume in drive E is OlsonCrk2 volume serial Number is EE56-61D9 Directory of E:\ 01/27/2015 08:31 AM 9,224 OlsonCreek2_Locations_nad27.pdf 01/27/2015 08:13 AM 8,903 OlsonCrk2_AbnormalPressurezones.pdf 01/27/2015 08:13 AM 9,395 OlsonCrk2_LogsRun_List.pdf 01/27/2015 08:12 AM 9,042 OlsonCrk2_Markers_List.pdf 01/27/2015 08:12 AM 8,935 OlsonCrk2_0ilGasshows_List.pdf 5 File(s) 45,499 bytes Total Files Listed: 5 File(s) 45,499 bytes 0 Dir(s) 0 bytes free Page 1 .214113 25331 0000v AGSC S1OZ NL K NVr ��o� ��P�- 3MM33 GO 5 �,p16 OLSON CREEK#2, API# 50-283-20174-00-00 Location CONFIDENTIAL DATA LOGGED /x/201$ M K.BENDER Depth MD Depth TVD Type of Coordinate Coordinate Surface 0' 0' Latitude,decimal degrees 61.246027 Longitude,decimal degrees -151.136263 Coordinate System Datum: NAD27(NADCON); Ellipsoid: Clarke 1866 TD 11,589' 9,657' Latitude,decimal degrees 61.248728 Longitude,decimal degrees -151.170235 Coordinate System Datum: NAD27(NADCON); Ellipsoid:Clarke 1866 • JAN 2 7 2015 AOGCC NO LONGER OLSON CREEK#2, API# 50-283-20174-00-00 CONFIDENTIAL Geologic Markers NOV 0 5 2015 CONFIDENTIAL Name Measured Depth TVD Sterling 250' 250' Beluga 2260' 1951' Tsuga 2-5 3270' 2744' Tsuga 2-6 3840' 3198' Tyonek 7318' 5937' Chickaloon 11320' 9430' • • o _ $ \ t $ d \ 0. _R _f _R CO To ` , C > C CA r § /I $ % \ / $ k ( z 0 ( g a = w < or TO• 2 - _- _- _- > 13 \ \ / \ & N a § cc 9 9 2 / et k k CY E E —1 \ -J 0 0 ec o E c *in \ L \ § k k z w , 0. © 0 a E E 0 «0 c 0 LL c co a -J � -1 ir. k -1 Z 0 2 2 0 ° p O Z = Y 0 / % § W 0 7 cl)7 k k \ d z z o ® ® 0. 0. 2 J £ / \ 0 / f k k 0 ) / f 3 3 \ \ \ / / O 0 0 \ < < I C 5 = % # To To ƒ 2 2 } } • ) f , m Q 0) \I R I— E Ce I i % 5 0 0 X X 2 2 « _ - « « - 0) § § § \ § § 0 \ \ \ \ \ \ 0 « - « - - « \ d (NCV \\ CO 0.5 _ $ CO CO § k C =C tC LL • $ 2 0 2 2 2 O 1 1 1 1 \ 0 • • ECE VED JAN272015 sAOGCQ OLSON CREEK#2, API#50-283-20174-00-00 Oil and Gas Shows CONFIDENTIAL Name Measured Depth TVD Tyonek 9,626'-9,655' 7,933'-7,979' NO LONGER CONFIDENTIAL IIV t 5 2016 • • JAN 2 7 2015 AOGCC OLSON CREEK#2, API#50-283-20174-00-00 NO LONGER CONFIDENTIAL Abnormal Pressure Zones NOV U52016 CONFIDENTIAL Name Measured Depth TVD NONE NONE NONE Cook Inlet Energy, LLC 2532` 601 W. 5th Avenue, Suite 310 Anchorage, Alaska 99501 Phone: (907) 334-6745 Fax: (907) 334-6735 DATA TRANSMITTAL Date: January23, 2015 To: Meredith Guhl From: Barbara Kruk for Courtney Rust AOGCC Cook Inlet Energy, LLC 333 W. 7th Ave, Suite 100 601 W. 5th Avenue, Suite 310 Anchorage, AK 99501 Anchorage, AK 99501 Phone: (907) 279-1433 Phone: (907)433 - 3802 FAX: (907) 334 -6735 TRANSMITTAL DESCRIPTION NO LONGER Well Data for Olson Creek #2, API#50-283-20174-00-00 CONFIDENTIAL In accordance with Alaska Regulations 20 AAC25.537(b), we request NUV 0 5 1016 that confidentiality be extended to all of the following information. Item No. Qty Description 1 1 CD - Olson Creek#2 Directional Survey Dated: 1-23-15; 4 Files; Format: PDF, Excel, ASCII Please sign below to ackn a_ c a'• . Received By: Date:Angela K. Singh /.on Returned to Cook Inlet Energy, LLC Date Accepted By: Transmittals CIE AOGCC.xlsx/AOGCC 1-23-15 OlsonCrk2 _______11111_,, j a 11 R iitt, I / er a t. , , , , ,, c,bio E -- , ,,1 ,. ,,,, .. I, l a31ISS. �J C� / `a� -- -, ,,,>'' l f' [ �, , speed II Ir - �� C L F Isesse S 3-aor19 -00-00 V ted-4A-Thissa_. 51/41rve a V ! S agocc_olsoncrk2_dirsurvey_1-23-15.txt volume in drive E is OlsonCrk2 volume serial Number is E450-6CFB Directory of E:\ 10/27/2014 08:27 AM 155,506 Olson #2 - Definitive survey.pdf 01/23/2015 01:47 PM 13,904 olsonCreek2_dirsurvey_final .prn 01/23/2015 01:48 PM 15, 527 OlsonCreek2_dirsurvey_final .txt 01/23/2015 01:47 PM 20,952 OlsonCreek2_dirsurvey_final .xlsx 4 File(s) 205,889 bytes Total Files Listed: 4 File(s) 205,889 bytes 0 Dir(s) 0 bytes free Page 1 • c)/y- ti � S! 1 Cook Inlet Energy, LLC 601 W. 5th Avenue, Suite 310 Anchorage, Alaska 99501 Phone: (907) 334-6745 Fax: (907) 334-6735 DATA TRANSMITTAL Date: August 22,2008 To: Meredith Guhl From: Barbara Kruk AOGCC Cook Inlet Energy, LLC 333 W. 7th Ave, Suite 100 601 W. 5th Avenue, Suite 310 Anchorage, AK. 99501 Anchorage, AK 99501 Phone: (907) 279-1433 Phone: (907)433 - 3802 FAX: (907)334 -6735 TRANSMITTAL DESCRIPTION Qty Description 1 Set Washed & Dried Samples from Olson Creek- 2 Box 1 of 8 - Dry Samples Interval Depths (150'-1320') Box 2 of 8 - Dry Samples Interval Depths (1320'-2760') Box 3 of 8 - Dry Samples Interval Depths (2760'-4350') Box 4 of 8- Dry Samples Interval Depths (4350'-5730') Box 5 of 8- Dry Samples Interval Depths (5730'-7620') Box 6 of 8- Dry Samples Interval Depths (7620'-8760') Box 7 of 8- Dry Samples Interval Depths (8760'-10230') Box 8 of 8- Dry Samples Interval Depths (10230'-11589') Np 1-ONG -11 CONFIDEN1IAL 0 5 2.01 NO 1-0" p a_ lop 201tt CONFIDENTIAL DATA This data MUST BE RETURNED to Cook Inlet Energy, LLC without retention of any copies, notes or extracts thereof. REC Please sign below to acknowle eceipt. ilEc, 1$ 1014 Received By: ��c `�� Date: C Angela K. Singh AOC Returned to Cook Inlet Energy, LLC Date Accepted By: AOGCC_Olson_Crk-2.xlsx/Template_1pg Date Modified:12/19/2014 bk A 1, • RECEIVED Cook Inlet Energy DEC 11 2014 AOGCC December 11, 2014 Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Re: Olson#2 Well Completion Cook Inlet Energy, LLC: Olson Creek#2 Permit to Drill No: 214-113 Dear Ms. Foerster, Please find our enclosed 10-407 Well Completion for the Olson Creek#2 well. Included is the 10-407 form, drilling summary, wellbore schematic, final survey and a cementing report. If you have any questions,please contact me at(907)-727-7404. Sincerely, del" Conrad Perry Drilling Manager—Cook Inlet Energy 601 W.5th Avenue,Suite 310,Anchorage,AK 99501 (907)334-6745*(907)334-6735 fax r ., STATE OF ALASKA • ALL OIL AND GAS CONSERVATION COSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ •Abandoned Dpended [1b.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory 0 GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 5.Date Comp.,Susp.,or 12.Permit to Drill Number: COOK INLET ENERGY,LCC •- 10/5/2014• 214-113 /3/1-53y 3.Address: 6.Da e Spudded: 13.API Number: 601 W 5TH AVE,SUITE 310 ANCHORAGE,ALASKA 99501 8/28/2014 $ 50-283-20174-00-00 • 4a.Location of Well(Govemmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 2593'FWL,2931'FNL,Sec 6,T13N, R1 OW SM 9/25/2014. OLSON CREEK#2 1 Top of Productive Hon N/A 8.KB(ft above M;318 15.Field/Pool(s): GL(ft above MSL 291.5 Total Depth: 1740 FNL, 1924 FWL Sec 01-T13N-R11W 9.Plug Back Depth(MD+TVD) EXPLORATION , 8360'/6822'U ;,,yy�� 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TV 16.Property Designation: 5% Surface: 0 264 99CD•0 ;( * 299832 + 1'q•ts Zone- 4 ,11,589'/9,657' MHT 9300062 MUT q3 (off TPI: J x- y- Zone- 11.SSSV Depth(MD+T`17.Land Use Permit: Total Depth: x- 293909.17 y- 2,650,218.15 Zone- 4 N/a MHT 9300062 18.Directional Survey: Yes U . No U 19.Water Depth,if Offshc 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (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: Quad combo,CCL 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD_ AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20" 133 L80 0 117 0 117 -- N/A 9 5/8" 47 P110 0' 2023 0 1,790 12 1/4" Lead:525 sxs/12.5 ppg Tall:280 sxs 15.2 ppg N/A 7" 26 L80 0 1883 0 1699 8.5" 7" 29 P110 1880 8475 1699 6,922 8.5" 15.8 ppg 323 sxs Class G N/A 24.Open to production or injection? Yes ❑ No ❑✓ 25. TUBING RECORD If Yes,list each interval open(MD+TVD of Top and Bottom;Perforation SIZE I DEPTH SET(MD) (PACKER SET(MD/TVD) Size ,anD 0 ,AdOn N/A 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. _t I�a iiRECEIVED Was hydraulic fracturing used during completion Yes u No 2' '' DEPTH INTERVAL(NAMOUNT AND KIND OF MATERIAL USED DEC 11 2014 AOGCC 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): Flow Test Date of Test: Hours Tested: Production for Oil-Bbl: IGas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 10/1/2014 2/10/1900 Test Period -► gas insufficient to measure 2132 OPEN Flow Tubing Casing Press: Calculated Oil-Bbl: IGas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 45 N/A 24-Hour Rate - gas insufficient to measure 1248 26.4 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ . No Q Sidewall Cores Acquired? Yes ❑ No Q - 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 25.07 Form 10-407 Revised 10/2012 6 ./7 /,--- CONTINUED Ojq REVERSEABC MS JAN - 9 20`� ubmit original on • 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? 1Yes ❑o 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 Sterling 250' 250' Beluga 2260' 1951' Tsuga 2-5 3270' 2744' Tsuga 2-6 3840' 3198' Tyonek 7318' 5937' Chickaloon 11320' 9430' Formation at total depth: Chickaloon 31. List of Attachments: 10-407,wellbore schematic,drilling summaries,directional plan, logs 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Courtney Rust A Email: courtney.rust @ cookinlet.net Printed Name: Conrad r - Title: Drilling Manager tor, Signature: / Phone: 907-727-7404 Date: 12/11/2014 INSTRUCTIONS General: This form is designed for submi ing 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 ND 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 10/2012 Olson Creek Final Wellbore 10-5-14 • 7 --: A . , . , .. .: : .: _ 7"Csgpunch@301' - 20" L80 117'TVD n 133# BTC 127'MD 12 1/4"Hole 9 5/8" L-80 1,790'TVD 47# BTC 2023'MD ll t` — Top of Retainer©7,455' Perforations 7470'-7580' =�` a -" - 8.5"Hole 6,927'TVD 9 bbls cement below retainer 8,480'MD Top of Cement @ 8,360' ' � ' � ILL L,F' s�1tr y Top of Retainer @ 8,410' 7" L80 1,699'TVD „,;,./!;;.-*J.* ..iii_ 26# DWC 1,883'MD {t i 1 ' 7"Shoe * ' '"F 7" P110 6,922'TVD `* 29# DWC 8475'MD Bottom of Cement @ 8,575' "`+.':�"4' 6 1/8"Hole 11,589'M D 1.- 9,657'TVD • • Olson Creek 2 Drilling Summaries PTD: 214:113 8-8-14-8-27-14 Rig move, site prep, rig up diverter. 8-28-14 SPUD. Drilled ahead to 372'. 8-29-14 Drill ahead from 372'-1581'. 8-30-14 Drilled ahead from 1581'-2023'. Condition mud and circulate hole clean. Back ream out of hole to 190'. RIH to bottom. Circulated hole clean. POH. LD BHA. 8-31-14 RU to run casing. Pick up shoe track,test floats. Run 9 5/8" 47# P110 BTC casing to 2,023'. Head up casing and circulate. CEMENT CASING: PUMP 5 BBLS WATER, KICK OUT BOTTOM PLUG. TEST LINES TO 3000 PSI. PUMP 33 BBLS SEALBOND SPACER @10 PPG. MIX & PUMP 198 BBLS, 525 SX. LEAD CEMENT, YIELD 3.13, MIX H2O 12.02 GAL/SX, AT 12.5 PPG. MIX & PUMP 59 BBLS, 260 SX. TAIL CEMENT, YIELD 1.27, MIX H2O 5.72 GAL/SX, AT 15.2 PPG. KICK OUT TOP PLUG, AND DISPLACE WITH 148 BBLS 9 5 #/GAL MUD. AT 2.5 BPM, FCP=640 PSI, BUMP PLUG 500 OVER AT 1140 PSI. BLEED BACK 2.5 BBLS.FLOATS HELD. 49 BBLS CEMENT TO SURFACE. CIP@ 13:30. WOC. Flush cement unit. Nipple down annual diverter. 9-1-14 Nipple down diverter system. Install 11x5K multibowl wellhead. NU BOPE. Stack rams. Cont NU. 9-2-14 Continue NU. Start BOPE test 9-3-14 Cont BOPE test. PU BHA. Drill out shoetrack. Perform FIT to 15.06ppg EMW. Drill ahead to 2215'. 9-4-14 Drill ahead from 2215'-3641'. 9-5-14 Drill ahead from 3641-4637'. Short trip to 3,181'. Circulated. RIH to bottom. Drill ahead to 4879'. • • 9-6-14 Drill ahead from 4879-6019'. CBU. POH to 5550'. CBU. POH to 5070'. 9-7-14 POH to 4631'. CBU. PU singles and start running in the hole. Drill ahead from 6019'- 6820'. 9-8-14 Drill ahead from 6820'-7543'. POH. 9-9-14 Cont POH for BOPE test.Test BOPE. 9-10-14 CBU. POH. PU new BHA. PJSM. MWD test. RIH with BHA#3. CBUx2 at shoe. RIH. Shut in well and CBU through choke as a precaution. Check flow. Drill from 7543'-7731'. 9-11-14 Drill ahead from 7731'-8480'. CBU. TD for 8.5" hole. POH. 9-12-14 POH. 9-13-14 Finish POH. Pull wear bushing and set test plug. Test 7" BOPE. RU Weatherford for casing run. PJSM. PU shoe track. 9-14-14 RIH with casing to bottom at 8480'. Circulate hole clean. 9-15-14 PJSM with cementers. RU for cement. Baker pump 2bbls water and pressure test lines T/3000psi. Drop plug, build and pump 10.5ppg 40 bbl spacer. Pump 66 bbls of 15.8ppg class G cement(yield = 1.15, Gal/sk=4.93, 370 cuft.) reciprocating casing while pumping, displace with 315.8 bbls, Bumped plug. Checked floats, Cement in place at 03:38. Rig down landing joint. Drain and wash out stack. Land pack off and test void to 5000. Rig down casing tools. RD and LD tools. 9-16-14 LD 5". PU test plug.Test BOPE. 9-17-14 RIH. 9-18-14 • i RIH. Drill out shoe track. From 8,392'-8,480'. Drill ahead from 8,480'-8,763' 9-19-14 Drill ahead from 8,763'-8,911'. 9-20-14 Drill ahead from 8,911'-9,338'. 9-21-14 Drill ahead from 9,338'-9,880' 9-22-14 Drill ahead from 9,880'-10,414' 9-23-14 Drill ahead from 10,414'-10,849' 9-24-14 Drill ahead from 10,849'-11,504' 9-25-14 Drill ahead from 11,504'-11,589' and TD the well. POH 9-26-14 BOPE test. RIH with cement retainer at 8,410'. Pressure tested casing. 9-27-14 PJSM. Cement casing with 10 Bbls ahead of water followed by 9 Bbls cement, 44 sx, yeild 1.15, H2O GPS 4.91, @15.8 PPG. Displace cement with 88 Bbls of mud. Squeeze away 5 Bbls water, 6 Bbls cement, unsting and drop 3 Bbls cement on top of retainer. CIP@4:30. Maintained 900 PSI on annulus while displacing cement. RD cementers. POH. RU wireline. Run CBL. POH. PU 7" Casing scraper assy. 9-28-14 RIH with assy to 8,310'. Pump downhole, 50bbl hi-vis pill. Displace well with 3% KCL brine. Circulate. 9-29-14 Circulate and filter brine 9-30-14 Finish filtering. POH. LD tools. PJSM. RIH with perf assy to 7,584'. RU wireline. 10-1-14 Correlate and space out perf assy. Set packer. Pressure tested lines. Drooped bar. Flow tested well. • • 10-2-14 Flow tested well. 10-3-14 Flow tested well. POH to 5,155'. 10-4-14 POH for BOPE test. BOPE test. PJSM. PU retainer BHA. Sheared out of retainer at 35K over pickup.Verify set. Begin pressure testing Drill Pipe. 10-5-14 Pressure tested drill pipe. Pressure tested casing. Squeezed 10.7 bbls of cement below retainer. Unstung and placed 5 bbls of cement on top of the retainer. Pulled to 7,000' and circulated at 690 gpm, 3,968 psi. Saw trace cement returns to surface. `L �k LD drill string to 1,000'. RIH to 5,200'. Mixed and pumped 30 bbl Hi-Vis Pill. POH. LD Q X14" DP. Ru and tested casing and bottom cement plug to 2,500' PSI. . • Cook Inlet Energy Olson Olson Creek Unit Olson #2 Olson #2 Survey: Olson #2 Rig surveys Standard Survey Report 25 September, 2014 You created this PDF from an application that is not licensed to print to novaPDF printer(http://www.novapdf.com) • • Halliburton 41111 Survey Report Company: Cook Inlet Energy Local Co-ordinate Reference: Well Olson#2 Project: Olson TVD Reference: Rig191 ©318.50ft Site: Olson Creek Unit MD Reference: Rig191©318.50ft Well: Olson#2 North Reference: Grid Wellbore: Olson#2 Survey Calculation Method: Minimum Curvature Design: Olson#2 Rig Surveys Database: EDM 5000.1 Single User Db Project Olson Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Site Olson Creek Unit Site Position: Northing: 807,409.04 m Latitude: 61°14'44.211 N From: Map Easting: 91,398.42 m Longitude: 151°8'10.726 W Position Uncertainty: 0.00 ft Slot Radius: 13.200 in Grid Convergence: -1.00 ° Well Olson#2 Well Position +N/-S 0.00 ft Northing: 807,455.04 m Latitude: 61°14'45.698 N +E/-W 0.00 ft Easting: 91,401.87 m Longitude: 151°8'10.548 W Position Uncertainty 0.00 ft Wellhead Elevation: 0.00 ft Ground Level: 291.60 ft Wellbore Olson#2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) IGRF2010 7/21/2014 17.21 74.06 55,713 Design Olson#2 Rig Surveys Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 26.90 Vertical Section: Depth From(TVD) +NI-S +E/-W Direction (ft) (ft) (ft) (°) 26.90 0.00 0.00 279.69 Survey Program Date 9/25/2014 From To (ft) (ft) Survey(Wellbore) Tool Name Description 192.57 11,589.00 Olson#2 Rig surveys(Olson#2) MWD+SC+sag Fixed:v2:standard dec&axial correction+sag Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-5 +E/-W Section Rate Rate Rate (ft) (°1 (°) (ft) (ft) (ft) (ft) (°/100ft) (1100ft) (1100ft) 26.90 0.00 0.00 26.90 0.00 0.00 0.00 0.00 0.00 0.00 192.57 0.30 244.13 192.57 -0.19 -0.39 0.35 0.18 0.18 0.00 225.57 0.43 333.07 225.57 -0.12 -0.52 0.50 1.57 0.39 269.52 312.07 0.36 12.91 312.07 0.44 -0.61 0.68 0.32 -0.08 46.06 400.84 0.30 3.47 400.84 0.94 -0.53 0.68 0.09 -0.07 -10.63 491.46 1.90 286.38 491.44 1.60 -1.96 2.20 2.05 1.77 -85.07 580.42 3.85 281.57 580.28 2.62 -6.30 6.65 2.21 2.19 -5.41 670.98 6.56 280.24 670.46 4.15 -14.37 14.87 3.00 2.99 -1.47 759.47 9.12 280.53 758.12 6.33 -26.24 26.93 2.89 2.89 0.33 854.00 14.30 281.01 850.65 9.93 -45.08 46.11 5.48 5.48 0.51 9/25/2014 11'31-37AM Page 2 COMPASS 5000 1 Build 65 You created this PDF from an application that is not licensed to print to novaPDF printer(http://www.novapdf.com) • • Halliburton • Survey Report Company: Cook Inlet Energy Local Co-ordinate Reference: 1Mell Olson#2 Project: Olson TVD Reference: Rig191©318.50ft Site: Olson Creek Unit MD Reference: Rig191 @ 318.50ft Well: Olson#2 North Reference: Grid Wellbore: Olson#2 Survey Calculation Method: Minimum Curvature Design: Olson#2 Rig Surveys Database: EDM 5000.1 Single User Db Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W Section Rate Rate Rate (ft) (°) (°) (ft) (ft) (ft) (ft) (°/100ft) (1100ft) (°HOOft) 951.98 15.84 280.95 945.25 14.78 -70.09 71.58 1.57 1.57 -0.06 1,048.58 18.99 280.03 1,037.41 20.02 -98.52 100.48 3.27 3.26 -0.95 1,143.78 23.69 279.27 1,126.06 25.80 -132.66 135.11 4.95 4.94 -0.80 1,239.16 27.01 279.81 1,212.25 32.58 -172.93 175.94 3.49 3.48 0.57 1,334.74 31.83 280.14 1,295.48 40.72 -219.15 222.88 5.05 5.04 0.35 1,430.18 35.62 278.80 1,374.84 49.41 -271.41 275.86 4.05 3.97 -1.40 1,523.89 39.72 278.57 1,449.00 58.05 -328.01 333.10 4.38 4.38 -0.25 1,619.13 43.93 280.07 1,519.96 68.37 -390.66 396.59 4.54 4.42 1.57 1,714.72 47.37 278.39 1,586.77 79.30 -458.12 464.93 3.81 3.60 -1.76 1,809.03 47.58 278.06 1,650.52 89.24 -526.91 534.41 0.34 0.22 -0.35 1,904.20 49.80 278.31 1,713.34 99.42 -597.66 605.87 2.34 2.33 0.26 1,963.94 49.43 278.11 1,752.05 105.92 -642.70 651.36 0.67 -0.62 -0.33 2,049.07 49.51 277.95 1,807.37 114.96 -706.77 716.04 0.17 0.09 -0.19 2,076.55 49.05 278.53 1,825.29 117.94 -727.38 736.86 2.32 -1.67 2.11 2,171.30 46.34 277.67 1,889.06 127.83 -796.75 806.90 2.94 -2.86 -0.91 2,267.10 44.25 279.64 1,956.45 138.05 -864.06 874.96 2.63 -2.18 2.06 2,364.13 41.44 279.84 2,027.59 149.21 -929.08 940.94 2.90 -2.90 0.21 2,458.47 40.91 279.73 2,098.60 159.76 -990.29 1,003.05 0.57 -0.56 -0.12 2,556.54 39.14 279.55 2,173.69 170.33 -1,052.46 1,066.12 1.81 -1.80 -0.18 2,647.34 38.33 278.85 2,244.52 179.41 -1,108.55 1,122.93 1.01 -0.89 -0.77 2,742.36 38.06 278.75 2,319.20 188.40 -1,166.61 1,181.68 0.29 -0.28 -0.11 2,838.63 36.78 279.10 2,395.66 197.48 -1,224.40 1,240.17 1.35 -1.33 0.36 2,932.82 36.61 278.94 2,471.18 206.30 -1,279.99 1,296.45 0.21 -0.18 -0.17 3,026.09 36.02 278.27 2,546.33 214.57 -1,334.60 1,351.68 0.76 -0.63 -0.72 3,120.25 35.90 278.37 2,622.55 222.57 -1,389.31 1,406.95 0.14 -0.13 0.11 3,218.51 35.75 278.14 2,702.22 230.83 -1,446.23 1,464.45 0.21 -0.15 -0.23 3,313.09 36.14 278.35 2,778.79 238.79 -1,501.17 1,519.95 0.43 0.41 0.22 3,407.57 37.08 278.71 2,854.63 247.15 -1,556.89 1,576.28 1.02 0.99 0.38 3,502.35 37.08 279.33 2,930.24 256.11 -1,613.33 1,633.42 0.39 0.00 0.65 3,597.94 37.96 280.49 3,006.06 266.13 -1,670.68 1,691.64 1.18 0.92 1.21 3,693.20 37.54 280.33 3,081.38 276.67 -1,728.04 1,749.95 0.45 -0.44 -0.17 3,788.13 37.45 280.36 3,156.70 287.05 -1,784.88 1,807.73 0.10 -0.09 0.03 3,882.97 37.55 280.41 3,231.94 297.45 -1,841.67 1,865.46 0.11 0.11 0.05 3,978.37 38.34 280.74 3,307.17 308.22 -1,899.33 1,924.12 0.85 0.83 0.35 4,073.38 38.05 279.53 3,381.84 318.56 -1,957.16 1,982.86 0.84 -0.31 -1.27 4,164.93 38.44 280.72 3,453.75 328.52 -2,012.95 2,039.53 0.91 0.43 1.30 4,260.45 38.34 281.40 3,528.61 339.90 -2,071.17 2,098.83 0.45 -0.10 0.71 4,354.93 38.29 281.29 3,602.74 351.43 -2,128.60 2,157.38 0.09 -0.05 -0.12 4,448.85 39.01 281.33 3,676.09 362.93 -2,186.12 2,216.02 0.77 0.77 0.04 4,545.52 38.95 281.39 3,751.24 374.91 -2,245.74 2,276.80 0.07 -0.06 0.06 4,645.29 38.85 281.01 3,828.89 387.08 -2,307.19 2,339.43 0.26 -0.10 -0.38 4,740.90 38.88 280.85 3,903.33 398.45 -2,366.10 2,399.41 0.11 0.03 -0.17 4,836.23 38.74 280.38 3,977.62 409.46 -2,424.82 2,459.15 0.34 -0.15 -0.49 4,931.54 38.85 279.60 4,051.90 419.82 -2,483.63 2,518.86 0.53 0.12 -0.82 9/25/2014 11 31 37AM Page 3 COMPASS 5000 1 Build 65 You created this PDF from an application that is not licensed to print to novaPDF printer(http://www.novapdf.com) Halliburton Survey Report Company: Cook Inlet Energy Local Co-ordinate Reference: Well Olson#2 Project: Olson TVD Reference: Rig191©318.50ft Site: Olson Creek Unit MD Reference: Rig191 @ 318.50ft Well: Olson#2 North Reference: Grid Wellbore: Olson#2 Survey Calculation Method: Minimum Curvature Design: Olson#2 Rig Surveys Database: EDM 5000.1 Single User Db Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +EI-W Section Rate Rate Rate (ft) (^) (>) (ft) (ft) (ft) (ft) (1100ft) (1100ft) (1100ft) 5,026.46 38.50 279.74 4,126.00 429.78 -2,542.11 2,578.18 0.38 -0.37 0.15 5,121.58 38.54 279.39 4,200.43 439.62 -2,600.52 2,637.42 0.23 0.04 -0.37 5,216.70 38.16 279.61 4,275.02 449.36 -2,658.73 2,696.43 0.42 -0.40 0.23 5,310.33 38.18 279.93 4,348.63 459.18 -2,715.75 2,754.30 0.21 0.02 0.34 5,404.91 38.24 278.35 4,422.95 468.47 -2,773.51 2,812.79 1.04 0.06 -1.67 5,501.96 37.80 278.43 4,499.41 477.20 -2,832.65 2,872.55 0.46 -0.45 0.08 5,596.16 38.53 278.39 4,573.47 485.71 -2,890.23 2,930.75 0.78 0.77 -0.04 5,691.28 38.38 279.09 4,647.96 494.70 -2,948.70 2,989.89 0.48 -0.16 0.74 5,784.41 38.14 279.11 4,721.08 503.82 -3,005.64 3,047.56 0.26 -0.26 0.02 5,880.95 38.38 278.82 4,796.89 513.13 -3,064.69 3,107.34 0.31 0.25 -0.30 5,979.71 37.94 279.27 4,874.54 522.73 -3,124.95 3,168.35 0.53 -0.45 0.46 6,073.62 37.47 279.12 4,948.84 531.90 -3,181.65 3,225.78 0.51 -0.50 -0.16 6,168.03 37.58 279.94 5,023.72 541.42 -3,238.36 3,283.29 0.54 0.12 0.87 6,263.28 36.95 279.48 5,099.52 551.15 -3,295.21 3,340.96 0.72 -0.66 -0.48 6,359.76 37.45 279.93 5,176.37 560.99 -3,352.70 3,399.29 0.59 0.52 0.47 6,455.27 37.45 281.26 5,252.19 571.67 -3,409.79 3,457.36 0.85 0.00 1.39 6,549.97 37.14 281.02 5,327.53 582.75 -3,466.08 3,514.72 0.36 -0.33 -0.25 6,644.93 37.34 280.17 5,403.13 593.32 -3,522.57 3,572.18 0.58 0.21 -0.90 6,740.30 37.00 278.33 5,479.13 602.58 -3,579.43 3,629.79 1.22 -0.36 -1.93 6,833.96 37.27 278.73 5,553.79 610.97 -3,635.35 3,686.32 0.39 0.29 0.43 6,927.89 37.47 278.28 5,628.44 619.40 -3,691.74 3,743.32 0.36 0.21 -0.48 7,024.06 37.65 278.03 5,704.68 627.72 -3,749.77 3,801.92 0.25 0.19 -0.26 7,117.56 37.78 278.18 5,778.64 635.78 -3,806.39 3,859.10 0.17 0.14 0.16 7,213.22 38.07 278.03 5,854.10 644.07 -3,864.60 3,917.87 0.32 0.30 -0.16 7,311.02 37.71 278.48 5,931.28 652.69 -3,924.04 3,977.92 0.46 -0.37 0.46 7,404.55 37.50 279.07 6,005.38 661.40 -3,980.45 4,034.98 0.45 -0.22 0.63 7,496.38 36.45 279.24 6,078.74 670.19 -4,034.97 4,090.21 1.15 -1.14 0.19 7,594.55 34.45 278.80 6,158.71 679.12 -4,091.20 4,147.14 2.05 -2.04 -0.45 7,690.35 32.94 280.11 6,238.42 687.84 -4,143.63 4,200.28 1.75 -1.58 1.37 7,783.94 30.62 280.25 6,317.97 696.54 -4,192.14 4,249.57 2.48 -2.48 0.15 7,879.51 29.19 280.89 6,400.81 705.28 -4,238.98 4,297.21 1.53 -1.50 0.67 7,975.42 27.87 281.26 6,485.07 714.07 -4,283.93 4,343.00 1.39 -1.38 0.39 8,071.40 28.44 280.14 6,569.70 722.48 -4,328.43 4,388.28 0.81 0.59 -1.17 8,167.73 28.53 280.44 6,654.37 730.69 -4,373.64 4,434.22 0.18 0.09 0.31 8,256.91 28.78 280.95 6,732.62 738.62 -4,415.66 4,476.98 0.39 0.28 0.57 8,356.31 29.79 282.44 6,819.32 748.49 -4,463.26 4,525.57 1.25 1.02 1.50 8,436.94 30.13 282.86 6,889.18 757.31 -4,502.55 4,565.78 0.50 0.42 0.52 8,498.47 30.63 284.21 6,942.26 764.59 -4,532.80 4,596.83 1.38 0.81 2.19 8,561.31 31.12 286.43 6,996.19 773.11 -4,563.90 4,628.91 1.97 0.78 3.53 8,657.02 30.15 285.14 7,078.55 786.39 -4,610.82 4,677.40 1.22 -1.01 -1.35 8,753.50 30.97 287.54 7,161.63 800.20 -4,657.89 4,726.12 1.52 0.85 2.49 8,846.49 29.32 285.90 7,242.04 813.65 -4,702.60 4,772.46 1.98 -1.77 -1.76 8,878.14 28.89 284.88 7,269.69 817.73 -4,717.44 4,787.78 2.07 -1.36 -3.22 9/25/2014 11.31:37AM Page 4 COMPASS 5000 1 Build 65 You created this PDF from an application that is not licensed to print to novaPDF printer(http://www.novapdf.com) • Halliburton III Survey Report Company: Cook Inlet Energy Local Co-ordinate Reference: Well Olson#2 Project: Olson TVD Reference: Rig191 @ 318.50ft Site: Olson Creek Unit MD Reference: Rig191 @ 318.50ft Well: Olson#2 North Reference: Grid Wellbore: Olson#2 Survey Calculation Method: Minimum Curvature Design: Olson#2 Rig Surveys Database: EDM 5000.1 Single User Db Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W Section Rate Rate Rate (ft) (°) (°) (ft) (ft) (ft) (ft) (°/100ft) (1100ft) (1100ft) 8,972.91 28.60 282.06 7,352.79 828.35 -4,761.75 4,833.24 1.46 -0.31 -2.98 9,068.48 28.11 281.52 7,436.89 837.63 -4,806.18 4,878.60 0.58 -0.51 -0.57 9,159.62 27.90 281.18 7,517.36 846.05 -4,848.14 4,921,38 0.29 -0.23 -0.37 9,252.30 26.56 279.49 7,599.77 853.67 -4,889.85 4,963.77 1.67 -1.45 -1.82 9,347.42 26.92 279.72 7,684.71 860.81 -4,932.05 5,006.57 0.39 0.38 0.24 9,442.45 26.18 277.71 7,769.72 867.26 -4,974.03 5,049.04 1.22 -0.78 -2.12 9,533.98 26.55 277.68 7,851.73 872.70 -5,014.31 5,089.66 0.40 0.40 -0.03 9,629.74 27.31 281.43 7,937.12 879.91 -5,057.05 5,133.01 1.94 0.79 3.92 9,721.38 26.97 280.76 8,018.67 887.96 -5,098.08 5,174.80 0.50 -0.37 -0.73 9,819.64 26.69 279.52 8,106.35 895.77 -5,141.73 5,219.14 0.64 -0.28 -1.26 9,909.38 27.09 278.44 8,186.39 902.10 -5,181.82 5,259.73 0.70 0.45 -1.20 10,006.33 27.08 280.14 8,272.70 909.23 -5,225.38 5,303.86 0.80 -0.01 1.75 10,101.00 26.95 281.05 8,357.05 917.13 -5,267.64 5,346.86 0.46 -0.14 0.96 10,193.08 27.21 278.16 8,439.03 924.12 -5,308.96 5,388.77 1.46 0.28 -3.14 10,290.20 26.69 279.44 8,525.61 930.85 -5,352.46 5,432.77 0.80 -0.54 1.32 10,383.06 27.44 281.08 8,608.30 938.38 -5,394.03 5,475.02 1.14 0.81 1.77 10,474.17 27.25 280.20 8,689.23 946.11 -5,435.16 5,516.86 0.49 -0.21 -0.97 10,570.02 27.44 277.35 8,774.37 952.82 -5,478.66 5,560.87 1.38 0.20 -2.97 10,665.06 28.11 281.16 8,858.47 959.96 -5,522.35 5,605.14 2.00 0.70 4.01 10,759.46 27.31 277.67 8,942.05 967.15 -5,565.64 5,649.02 1.92 -0.85 -3.70 10,850.83 28.12 280.86 9,022.94 974.01 -5,607.56 5,691.50 1.85 0.89 3.49 10,947.68 28.84 282.28 9,108.07 983.28 -5,652.80 5,737.65 1.02 0.74 1.47 11,042.04 29.81 284.86 9,190.34 994.13 -5,697.71 5,783.75 1.69 1.03 2.73 11,136.86 30.30 287.41 9,272.41 1,007.33 -5,743.32 5,830.93 1.44 0.52 2.69 11,228.11 30.57 289.79 9,351.09 1,022.08 -5,787.12 5,876.58 1.35 0.30 2.61 11,322.08 31.92 291.01 9,431.43 1,039.08 -5,832.79 5,924.47 1.59 1.44 1.30 11,419.20 31.95 292.11 9,513.85 1,057.95 -5,880.57 5,974.74 0.60 0.03 1.13 11,512.71 32.84 292.90 9,592.81 1,077.13 -5,926.85 6,023.59 1.05 0.95 0.84 11,552.18 32.81 291.90 9,625.98 1,085.29 -5,946.63 6,044.46 1.38 -0.08 -2.53 11,589.00 32.81 291.90 9,656.92 1,092.73 -5,965.14 6,063.96 0.00 0.00 0.00 Checked By: Approved By: Date: 9/25/2014 11 31 37AM Page 5 COMPASS 5000 1 Build 65 You created this PDF from an application that is not licensed to print to novaPDF printer(http://www.novapdf.com) • • Cook Inlet Energy,LLC CASING&CEMENTING REPORT Lease&Well No. Beluga-Olsen Creek#2 Date 4-Sep-14 County Kenai State Alaska Supv. Evan Harness Surface Casing TD 2023.00 Shoe Depth: 2023.00 PBTD: Casing(Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make Length Bottom Top FLOAT SHOE 9.625 47 L-80 BTC Baker 1.89 2023.00 2,021.11 1 9.625 47 L-80 BTC TUBOSCOPE 46.16 2021.11 1,974.95 FLOAT COLLAR 9.625 47 L-80 BTC Baker 2.02 1974.95 1,972.93 45 9.625 47 L-80 BTC TUBOSCOPE 1,978.11 1972.93 -5.18 _ Totals 2,028.18 Csg Wt.On Hook: 95,300 Type Float Collar: Baker Non Rotating No.Hrs to Run: 5.5 Csg Wt.On Slips: N/A Type of Shoe: Float Casing Crew: WEATHERFORD Fluid Description: Spud Mud Liner hanger Info(Make/Model): N/A Liner Top Packer?: Yes X No Liner hanger test pressure: N/A Centralizer Placement: 1 PER JOINT FIRST 4 JOINTS,THEN EVERY 3RD JOINT TO SURFACE. CEMENTING REPORT Preflush(Spacer) Type: TUNED SPACER Density(ppg) 10 Volume pumped(BBLs) 33 Lead Slurry Type: I Yield(Ft3/sack): 2.13 Density(ppg) 12.5 Volume (BBLs/sacks): 198/525 Mixing/Pumping Rate(bpm): 3.5 Tail Slurry Type: I Yield(Ft3/sack): 1.27 Density(ppg) 15.2 Volume (BBLs/sacks): 58.7/260 Mixing/Pumping Rate(bpm): 3.5 I- Post Flush(Spacer) Type: N/A Density(ppg) Rate(bpm): Volume: cc LT Displacement: Type: Mud Density(ppg) 9 Rate(bpm): 5 Volume(actual/calculated): 148/149 FCP(psi): 1,200 Pump used for disp: TRUCK Plug Bumped? X Yes No Bump press 1990 Casing Rotated? Yes X No Reciprocated? Yes X No %Returns during job 100 Cement returns to surface? X Yes No Spacer returns? X Yes No Vol to Surf: 49 Cement In Place At: 13:30 Date: 8/31/14 Estimated TOC: SURFACE Method Used To Determine TOC: Visual verification before making final casing cut. Remarks: Pumped job per design. No issues encountered. Floats held.Displaced as calculated. r • Cook Inlet Energy,LLC CASING&CEMENTING REPORT Lease&Well No. Beluga-Olsen Creek#2 Date 14-Sep-14 County Kenai State Alaska Supv. Evan Harness Intermediate Casing TD 8480.00 Shoe Depth: 8475.00 PBTD: Casing(Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make Length Bottom Top Rino shoe/float 8" DWC Baker 4.00 2 jts 7" 29# P-110 DWC TUBOSCOPE 81.90 FLOAT COLLAR 7" 29# p-110 DWC Baker 1.20 153 jts 7" 29# P-110 DWC TUBOSCOPE 6,479.71 48 jts 7" 26# L-80 DWC TUBOSCOPE 1,879.85 pup 7" 26# L-80 _ DWC TUBOSCOPE 3.25 RKB to land out 28.19 Totals 8,478.10 Csg Wt.On Hook: 95,300 Type Float Collar: Baker No.Hrs to Run: 24 Csg Wt.On Slips: N/A Type of Shoe: Float Casing Crew: WEATHERFORD Fluid Description: 9.8ppg MI water based Liner hanger Info(Make/Model): N/A Liner Top Packer?: Yes X No Liner hanger test pressure: N/A Centralizer Placement: 1 PER JOINT FIRST JOINTS THROUGH 29,THEN EVERY 3RD JOINT TO JOINT#50. CEMENTING REPORT Preflush(Spacer) Type: TUNED SPACER Density(ppg) 10.5 Volume pumped(BBLS) 32 Lead Slurry Type: G Yield(Ft3/sack): 1.15 Density(ppg) 15.8 Volume (BBLs/sacks): 1.15 Mixing/Pumping Rate(bpm): 5 Tail Slurry Type: N/A Yield(Ft3/sack): Density(ppg) Volume (BBLs/sacks): Mixing/Pumping Rate(bpm): Post Flush(Spacer) Type: N/A Density(ppg) Rate(bpm): Volume: LI Displacement: Type: Mud Density(ppg) 9.8 Rate(bpm): 5 Volume(actual/calculated): 315.5/314.14 FCP(psi): 1,200 Pump used for disp: TRUCK Plug Bumped? X Yes No Bump press 2000 Casing Rotated? Yes X No Reciprocated? Yes X No %Returns during job 100 Cement returns to surface? Yes X No Spacer returns? Yes X No Vol to Surf: 0 Cement In Place At: 3:38 Date: 9/15/14 Estimated TOC: 5,916 Method Used To Determine TOC: Calculated Remarks: Pumped job per design. No issues encountered. Floats held.Displaced as calculated.Bumped plug • • 10-2-14 Flow tested well. 10-3-14 Flow tested well. POH to 5,155'. 10-4-14 POH for BOPE test. BOPE test. PJSM. PU retainer BHA. Sheared out of retainer at 35K over pickup.Verify set. Begin pressure testing Drill Pipe. 10-5-14 Pressure tested drill pipe. Pressure tested casing. Squeezed 10.7 bbls of cement below retainer. Unstung and placed 5 bbls of cement on top of the retainer. Pulled to 7,000' and circulated at 690 gpm, 3,968 psi. Saw trace cement returns to surface. LD drill string to 1,000'. RIH to 5,200'. Mixed and pumped 30 bbl Hi-Vis Pill. POH. LD 4" DR Ru and tested casing and bottom cement plug to 2,500'PSI for 30 minutes. 10-6-14 Set bridge plug at 310' and tested to 2500 psi for 30 minutes. Punched 8 holes in 7" casing at 301'. Rigged up cementers and pumped 27 bbls 15.8 ppg cement down casing. Had returns after 21 bbls. Washed out top 5'of cement from wellhead flange. Tested cement plug to 700 psi for 30minutes. Observed 200 psi drop,but no returns up annulus. 10-7-14 RIH with drill pipe tagging cement inside 7"at 42'. Pump 5 bbls 15.8 cement with 3.5 bbls returns to cellar. Pump Y4 bbl cement down 7"x 9 5/8" annulus. WOC. Test 7"to 1500 psi,9 5/8"to 1500 psi for 30 minutes-good test. 10-8-14 to 10-17-14 Rig Move off location 10-18-14 Remove wellhead and cellar. Excavate around well to 9'below pad (5.5'below original grade) Witnessed by Lou Grimaldi. 10-19-14 Continued rig move 10-20-14 Welded on well identification cap and back filled to pad level. ' • • Wednesday, October 8, 2014 Olson Creek 1/2 PTD 214-113 Mr. Reg the summary of out Olson Creek# 2 Abandonment are Below - Operations went as Planned to the Point of pressure testing the Surface Plug prior to Nipple Down of BOP -The Cement Used for the Top Plug took forever to Set Up - I will call after sending this to Make Sure AOGCC are satisfied with our Efforts - Our Intent is to Move the Rig Off and then Recover the Wellhead and Weld on Abandonment Plate OUTLINE ABANDONMENT PROCEDURE Unscat Tcst Packcr Done 2. . _ _ - '.- - . -- . - ' _ . - _ - Done 37— , PON, Done top perf) Done 5. Set Retainer and establish injection rate Set EZSV Retainer - Set 25,000# Pipe weight Down - Pressure Tested to 2,500psi 6. Squeeze minimum 9 bbls 15.8 ppg cement (225 linear feet of 7") below retainer, leave 3 bbls cement on top. Squeezed 10BbI Below - Equalized 5Bbl on top p 7. Pick up 3 stands and circulate clean. Test Casing to 500 psi above injection pressure Pressure Tested to 2,500psi 500psi over final injection Pressure 8. POH. Pressure Tested Casing and Abandonment Plug to 2,500psi for 30min 9. Rig up eLine and punch 8 holes in 7" casing at 300'. Pressure up on 7" to ensure holes are clear. Set Bridge Plug at 310 - Pressure Tested to 2,500psi - Punch Holes in 7" at 301 10. Pick up 5" drill pipe and space out to 5' below wellhead. Close pipe rams. Rigged up on 7" Annulus Valve - Took Returns on 9 5/8 by 7" Annulus Valve 11. Circulate 7" x9 5/8" annulus clean. Cir and Pumped around 20Bbl Fresh Water • • Wednesday, October 8, 2014 Olson Creek#2 PTD 214-113 12. Circulate 15.8 ppg cement down drill pipe taking returns out 7" x 9 5/8" annulus. Clean Cement to Surface with 22Bbl Pumped - Pumped a total of 27Bbl with 6Bbl clean Cement to Surface 13. WOC. Tag cement. This is where we had trouble - We used a cement that was Blended for 7,500' with Cacl added - Not the Smartest thing I have done (took Forever to set up) - WOC 16hrs - Attempt to Pressure test 7" Surface Plug Would not test - Quick Pressure up (Less Than .5Bbl) to 1,000psi -Slow Bleed off to 700psi - WOC 22hrs Attempt to Pressure test - Quick Pressure up (Less than .5 Bbl) 1,300psi Slow Bleed to 800psi - Attempt Pressure test of 9 5/8 by 7 Quick Pressure up (Less than .5 Bbl) 1,000psi - Slow Bleed off to 700psi - Tag Cement in 7" at 42' 16' below Wellhead - Mobe BJ for Re-squeeze - Could not establish any Injection with 1,800psi - Re-Tag Cement in 7" at 42' 16' Below Wellhead - Attempt to Wash Down 3.5BbI/min - Could not wash Down - Cir Cement to 7" Annulus Valve - Shut CSO Rams (Blinds) - Apply 1,600psi squeeze pressure and hold same 3hr Very Slow Bleed off to 1,300psi - Fill 9 5/8 by 7 with .25Bbl Cement till cement returns at 9 5/8" Ann Valve - Pressure to 1,500psi and Hold 3hr Slow Bleed to 1,200psi - Bleed off Pressure - WOC 2hr - Pressure test 7" to 1,600psi for 30 min - Pressure test 9 5/8 by 7" to 1,500psi for 30min - Charts Attached 14. Nipple down BOPs. 15. Release rig for move. Guy, Cook Inlet Energy requests verbal approval to abandon Olson 2 in accordance with 20 AAC 25.112. Per our discussion we will down squeeze sufficient cement below a retainer set at 7,455' to cover 100' of 7" below the bottom perf at 7580'. We then plan to punch holes in the 7" casing at 300' and circulate cement into the 9 5/8"(surface casing) x 7" annulus, leaving cement inside the 7" to just below the wellhead. The following is an outline procedure and I have attached a proposed abandonment sketch. We are currently still flowing, but will start pulling out of hole shortly. • • Wednesday, October 8, 2014 Olson Creek#2 PTD 214-113 OUTLINE ABANDONMENT PROCEDURE 1. Unseat Test Packer 2. Changeover to 9.5 ppg mud circulating over choke 3. Check for flow, POH. 4. Pick up cement retainer and RIH on drill pipe to 7455' (15' above top perf) 5. Set Retainer and establish injection rate 6. Squeeze minimum 9 bbls 15.8 ppg cement (225 linear feet of 7") below retainer, leave 3 bbls cement on top. 7. Pick up 3 stands and circulate clean. Test Casing to 500 psi above injection pressure 8. POH. 9. Rig up eLine and punch 8 holes in 7" casing at 300'. Pressure up on 7" to ensure holes are clear. 10. Pick up 5" drill pipe and space out to 5' below wellhead. Close pipe rams. 11. Circulate 7" x9 5/8" annulus clean. 12. Circulate 15.8 ppg cement down drill pipe taking returns out 7" x 9 5/8" annulus. 13. WOC. Tag cement. 14. Nipple down BOPs. 15. Release rig for move. Conrad Drilling Manager Cook Inlet Energy, LLC 601 W. 5th Avenue STE 310 Anchorage, AK 99501 (907) 433-3816— Office (907) 727-7404 - Cell (907) 344-0584 - Home (907) 260-5356 - Cabin • • Wednesday, October 8, 2014 Olson Creek#2 PTD 214-113 From: Schwartz, Guy L(DOA) guy.schwartz@alaska.gov Subject: RE: Olson 2 PTD 214-113 Abandonment Date: October 3, 2014 at 9:31 AM To: Conrad Perry conrad.perry@cookinlet.net Cc: Courtney Rust courtney.rust@cookiniet.net, Evan Harness evan.harness@cooknlet.net, Bettis, Patricia K(DOA) patricia.bettis@alaska.gov Conrad, Verbal approval granted to P & A Olson #2 as proposed below with below modifications: 1) Pressure test and chart casing against lower retainer after dumping cement. (1500 psi min) 2) Cut off wellhead 5' below GL per 20 AAC 25.112 (d) and weld plate per 20 AAC 25.120. 3) Notify inspectors to witness. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office This email confirms your request for an inspection with the following information: Type of Test Requested: P&A Requested Time for Inspection: 10-06-2014 7:00 AM Location: Patterson 191, Olson Creek#2, Beluga • • Wednesday, October 8, 2014 Olson Creek#2 PTD 214-113 Name: Dmitry Smushkov E-mail: westmacdsm@cookinlet.net Phone Number: (907)4338967 Company: Cook Inlet Energy Other Information: Mr. Regg, We are plugging and abandoning Olson Creek#2. We plan to have our top plug in place by Monday 10/06/2014 07:00hrs. Please let us know if you have any questions. Thank you for your time. If you are not contacted within 12 hours, please notify Jim Regg at 907-793-1236. 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''` ;`"er''g -,.•,,..- '' -- ',.: 0.4^%.i ,r'• 'l r.• a• P 1 •.t • i' • • A:eress:. leave e �Olsonreek Page No. I I co xepre•ent•tlee: use Munn MM NeCerW0.1 Os. 9/90/2414 Time Wel Open. 22.31 IMO. Nm•Wee snot in: 1e.m 1.0044 TwM e1120 • w.a•. T.mp. w.aa, cm• w.•• wn. w. rmp ea.�mtle 0.... ew. no.p.x. e.o.r.o. onury aoe ooe usx >w.e.x, •.w.p.o. wt. N. cr4 ar weree • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Well File DATE: 10/21/2014 tAZk°� FROM: Jim Regg I SUBJECT: Surface P&A Inspection Supervisor Olson Creek#2 PTD 2141130 Cook Inlet Energy LLC AOGCC Inspector Lou Grimaldi traveled to Cook Inlet Energy (CIE)'s Olson Creek#2 location on October 18, 2014 to witness the surface abandonment of this exploration well. Initial depth of well cut-off was not sufficient. Mr. Grimaldi's email (10/18/14; 605pm) noted that CIE was instructed to excavate deeper to ensure cut-off casings to at least 3 feet below original ground level. A photograph of the marker plate to be installed and original cut off were provided by CIE on 10/19/14. AOGCC was not able to witness the final surface abandonment following additional efforts to excavate and cut the casings on 10/19/14 due to other inspection commitments. Photographs provided by CIE on 10/19 and 10/20/14 confirm the casings were cut at approximately 6 feet below original ground level with the marker plate installed (proper information)just prior to burial. Attachments: Emails; Photos (5) 2014-1020_Surface_Abandon_OlsonCk-2.docx Page 1 of 3 0 Surface Abandonment – Olson Creek #2 (PTD 2141130) Photos courtesy of Cook Inlet Energy 10/19 – 10/20/2014 h`" .. 4.-...— .. ti ,,..i.,* 4 y, ._. r. ..-•.r i - - Casing cut-off at insufficient depth (10/19/14)as observed by AOGCC ti 4• \ y �d ,- ; . , f , , . ft, �_, } \- r\ • �! � ) _ f 'f 1 r `' +` Q , \. . \ 2it1i13 .. C Marker plate with proper info 2014-1020_Surface_Abandon_OlsonCk-2.docx Page 2 of 3 S Measuring final cutoff after additional excavation; approximately 6 ft below original ground level a • °"9I I hai .:. Final abandonment with marker plate installed; just prior to burial • • 2014-1020 Surface_Abandon_OlsonCk-2.docx Page 3 of 3 • 61 SC,L CIL z- Ph z_4(150 Regg, James B (DOA) From: Grimaldi, Louis R (DOA) , )01Z4 a- Sent: Saturday, October 18, 2014 6:05 PM To: Regg, James B (DOA) Subject: Status Jim Just got back from Olsen Creek location. They haven't cut it off deep enough so they are digging away. I gave them instructions to get cutoff 3-5 feet below ground level and call me. I may be on the Grayling tomorrow so they may call you but my instructions were to standby if they could not get ahold of me (or you). I also want to move the Beluga sys inspection up a day to Friday as the weather is supposed to turn bad on Saturday afternoon and those wells take awhile: Your thoughts? Lou Grimaldi Petroleum Inspector Alaska Oil and Gas Conservation Commission (907)776-5402(Home) (907)252-3409(Cell) 1 61,511.. C1WAt Regg, James B (DOA) From: Rodney Maniaci <rodneymaniaci@gci.net> Sent: Sunday, October 19, 2014 9:10 AM 'Net 1012 J 0- To: Regg,James B (DOA) Cc: Grimaldi, Louis R(DOA) Subject: Well cap marker this morning Attachments: 20141019_084904.jpg 1 110 OKeku ic-L- - P7D z(41r3c Regg, James B (DOA) From: Grimaldi, Louis R (DOA) ZQ I t�— Sent: Sunday, October 19, 2014 11:38 AM � To: Rodney Maniaci Cc: Regg,James B (DOA) • Subject: RE:The felt is visible marking original ground level. Cutoff must be a minimum of 3' below ground level and closer to 5' would be better for your company. Make cutoff and document stub condition with pictures. Send notification and I will be available tomorrow for final inspection. Louis R. Grimaldi Petroleum Inspector Alaska Oil and Gas Conservation Commission 907-776-5402 (Home) 907-252-3409 (Cell) Lou.GrimaldiAlaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Lou Grimaldi at 907-252-3409 or Lou.Grimaldi@Alaska.gov. From: Rodney Maniaci [mailto:rodneymaniaci@gci.net] Sent: Sunday, October 19, 2014 9:12 AM To: Regg, James B (DOA); Grimaldi, Louis R (DOA); DSM At West Mac; Field Superintendent Subject: The felt is visible marking original ground level. '' .c.* 2c:1410 _03cz)-37 �P,..‘ Nie , i Otc� z PM Zt4-u 3o Regg, James B (DOA) From: Rodney Maniaci <rodneymaniaci@gci.net> Sent: Sunday, October 19, 2014 11:40 AM To: DSM At West Mac; Grimaldi, Louis R (DOA); Regg,James B (DOA); Field Superintendent Subject: Nearly 6 feet below original grade. Attachments: 20141019_112833jpg ppb itir tot 4114_ • • Gly uC.k- "� Z P Zt4{130 Regg, James B (DOA) From: WestMac DSM <WestMacDSM@cookinlet.net> eie 0121/14 Sent: Monday, October 20, 2014 4:52 PM To: Regg, James B (DOA); Grimaldi, Louis R (DOA); Evan Harness; Field Superintendant; Conrad Perry Subject: Olson Creek#2 Pictures prior to burial/ Attachments: Olson Creek#2_Abandonment_10-20-2014_002 jpg; Olson Creek#2_Abandonment_ 10-20-2014_001.jpg pf..,A„ totARA • �. ,i oi,,i . 907"1?. (71 westmacdsmacookinlet.net 1 • 2249)--V7 y DATA LOGGE UC-1 7 ' 1 5 2'3 WELL LOG TRANSMITTAL t oi+si2ot� M.K.BENDER A )OCk, To: AOGCC October 10, 2014 Attn: Makana Bender/Angela Singh 333 W. 7th Ave., Ste. 100 Anchorage, Alaska 99501-3572 RE: LWD Formation Evaluation Logs: Olson 2 AK-MW-0901597782 Olson 2 50-283-20174-00-00 2"&5" MD Triple Combo Log: 1 Color Logs 2" &5"TVD Triple Combo Log: 1 Color Logs 2" &5" MD XBAT-Triple Combo Log: 1 Color Logs 2"&5"TVD XBAT-Triple Combo Log: 1 Color Logs Digital Log Images, LAS Data, &DLIS Data w/verification listing 1 CD ROM PLEASE ACKNOWLEDGE RECEIPT BY RETURNING A SIGNED AND DATED COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Buster Bryant/Ben Schulze 6900 Arctic Blvd. Anchorage,Alaska 99518 Office: 907-273-3539/907-273-3536 Fax: 907-273-3535 Buster.Bryant@halliburton.com Benjamin.Schulze@halliburton.com Date: ‘0 \5 0 Signed: ' 4 -r 14 :` :dA, 'n `# &**I,a 522. 2:i fp ,"111:111,644.04,4.„, .,c. NMtsi:v'.—,14,6,4 s s . M1+F^F•4."i t a^a.., ,^1s " g*a ae 3 t "A r°'-"-_°`,,F, a.;. �E S ,f. ,l - t / ,I "fr —'1,-_-:.:,... �_, L . !. d E 'i` 1_. L., .— _ __ _ 333 West Seventh Avenue = t- o 1 I2NOR SI;As,,, PA R11,\,1 I,I. Anchorage Alaska 99501 3572 \:::L';',' \ / ".: '''7 279 ,z33 Conrad Perry Drilling Manager Cook Inlet Energy, LLC 601 W 5th Ave., Suite 310 Anchorage, AK 99501 Re: Exploratory Field, Exploratory Pool, Olson#2 Sundry Number: 314-534 Dear Mr. Perry: 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, , p__,?,,,,,,,L Cathy P. oerster Chair DATED this 3©c-1-e&- ay of September, 2014. Encl. • • _ .SVD STATE OF ALASKA _ ' 2 9 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION 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 CI Suspenl] Plug Perforations Perforate Pull Tubing❑ Time Extension❑ Operations Shutdown Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other: W'i_l( 1t. I/ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: COOK INLET ENERGY LLC • Exploratory ❑✓• Development ❑ 214-113+ 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: 601 W.5th AVE.SUITE 310,ANCHORAGE,AK 99501 50-283-20174-00-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 20 AAC 25.055 Will planned perforations require a spacing exception? Yes ❑ No ❑., • Olson#2 9.Property Designation(Lease Number): 10.Field/Pool(s): MHT 9300062 i MIH 13000(o3 Exploration 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 11,589'. 9,657'• 11,589' 9,657' N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 117' 20" 117' 117' 4450 1600 Surface 2,023' 9 5/8" 2,023' 1,790' 7930 6620 Intermediate 8,475' 7" 8,475' 6,922' 7240 5410 Production Liner Pedgration Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(a_ Packers and SSSV Type: Packers and 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: 20 Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑✓ , Stratigraphic❑ Development 1 Service ❑ 14.Estimated Date for 6/g/2014 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas El• WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: y-21-/y64/2044-WINJ ❑ GINJ ❑ WAG 0 Abandoned ❑ Commission Representative: 63 �,t f t,-- GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is ttue and correct to the best of my knowledge. Contact Courtney Rust 907-433-3809 Email courtnev.rust( cookinlet.net Printed Name Conrad Perry,Drilling Manager 727-7404 Title � 2 9 --/, Signature 7 Phone /// Date COMMISSION USE ONLY Conditions of approval: Notify Co sion so that presentative may witness Sundry Number: Plug Integrity ❑ BOP Test 2/ Mechanical Integrity Test ❑ Location Clearance EIC.+, faOther: ((! °` - �,() erZ.--) L Z�. ` 3- �� ) Kt eJO r t S-� r .►-�..ti l<C , (' kC u � - oI�'f I p' les ( tit.-se= ?s27f s') h,F•ad u Spacing Exception Required? Yes CI No Subsequent Form Required: 10 •-JO7 0,C,i-cam t�1 X-'11-'`-70 APPROVED BY Approved by:(747-y r--);,.6.,..04.,____ COMMISSIONER THE COMMISSION Date: 5-36„l y 2 I ' - I A Y Submit Form and Form 10-403(Revised 10/2012) i Approved applio ado 1 t the date of approval. A achments in Duplicate fi$CMS OCT -i 201 Cook Inlet Energy_ RECEIVED SEP 292014 September 29, 2014 AOGCC Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Re: Sundry Application for Change of Program Cook Inlet Energy, LLC: Olson Creek#2 API: 50-283-20174-00-00 PTD: 214-113 Dear Ms. Foerster, Cook Inlet Energy(CIE) requests permission to make the following changes to the Olson Creek 2 Permit to Drill 1. To abandon the 6 1/8" hole section as the logs did not reveal any hydrocarbons. 2. To perform a DST in the 7" casing with planned perforations at 8,190'-8,230'MD, 7,980'- 8,015'MD, and 7,470'-7,580'MD. In addition, CIE requests permission to vent or flare gas from the Olson well test for a period of 14 days according to 20 AAC 25.235 d (6). Maximum anticipated daily flaring is expected to be 10 MMSCF/D with a total expected not to exceed 40 MMSCF over the entire test. If you have any questions,please contact me at(907)-727-7404 Sincerely, Conrad Perry Drilling Manager—Cook Inlet Energy 601 W.5th Avenue,Suite 310,Anchorage,AK 99501 (907)334-6745*(907)334-6735 fax • Olson Creek*Proposed Wellbore 9-25-14 ii 20" L80 117'TVD w 133# BTC 12TMD Planned Perforations 7470'-7580' tiii 12 1/4"Hole 7980'-8015' 41 '4.49 5/8" L-80 1,790'TVD 8190'-8230' 47# BTC 2023'MD 8.5"Hole 6,927'TVD 8,480'MD Top of Cement @ 8,360' .��-_ Top of Retainer @ 8,410' �- 7" L80 1,699'TVD 7 26# DWC 1,883'MD � !, 7"Shoe t°d 7" P110 6,922'TVD 29# DWC 8475'MD Bottom of Cement @ 8,575' 1. ? r', 6 1/8"Hole 11,589'MD ------ — 9,657'TVD Olson CreekCurrent Wellbore 9-25-14 0 1 /8" L80 117'TVD 68# BTC 117'MD n* w . x e a 12 1/4"Hole 9 5/8" L-80 1,790'TVD 40# BTC 2,023'MD a a g 8.5"Hole 7" L80 1,699'TVD 4 26# DWC 1,883'MD 7" P110 6,922'TVD 29# DWC 8,475'MD 6 1/8"Hole 9,657'TVD Ali, 11 • Olson Creek PTD: 214-113 Current Status: Olson Creek well is an exploration well, we drilled to 11,589'MD and did not see any sign of hydrocarbons in the 6 1/8" hole. At this time we plan on abandoning that lower hole section and performing DSTs in the 7" casing section. General Well Information: Well type: Gas (exploration) MASP: 3527 PSI (calculations attached below) WELL NAME: Olson Creek 2 Well Information ENGINEER: Courtney Rust DATE: 27-Sep-14 Max EMW Estimated Hole Sizes Casing Size Estimated Range-Mud MD(ft) TVD(ft) (Pore Frac Grad at Mud Type Comments (in) (in) Weight(ppg) Pressure) Shoe 13 3/8" -- -- -- -- Conductor pipe 12 1/4" 9 5/8" 2,023 1,790 8.9 15.2 8.8 9.2 WBM Norm grad Based on offests 8 1/2" 7" 8,475 6,922 9.8 15.8 8.8 9.8 WBM Casing Plan (ENTER YELLOW CELLS MANUALLY Connection API rating Casing Size Wt(Ib/ft) Grade Collapse Tension MD(ft) TVD(ft) (in) Type OD(in) Burst(psi) (psi) (kips) 13 3/8" 68 L80 ETC -- -- -- -- 0 0 9 5/8" 40 L80 BTC 10.625 6870 5750 1161 2023 1790 7" 26 L80 BTC 7.875 7240 5410 641 8475 6922 Variables&Formulas Wellhead 5,000 psi Gas Gradient 0.10 psi/ft Pore Pressure Gradient 0.460 psi MAWP=(0.80 X CASING BURST)or Limiting Wellhead Pressure MASP=Lessor of(Frac Pressure @(0.052 X(MW+0.5ppg SF)X TVD)-GasGRD X TVD))or(Max Pore Pressure-(GasGRD X TVD)) MASCP=(0.80 X CASING BURST)-(MW-Backup FluidWt.)X.052 X TVD SF Burst=Burst Value/MASP SF Collapse=Collapse Value/((0.052 X Max EM WPore Pressure X TVD)-(gas gradient X TVD)) SF Tension=Tension Value/(Length X lb/ft) • Max Allowable Working Pressure MAWP=(0.80 X CASING BURST)or Limiting Wellhead Pressure Hole Sizes Casing Size MD(k) TVD(ft) Burst(psi) Safety Wellhead MAWP(psi) (in) (in) Factor (psi) 12 1/4" 9 5/8" 2,023 1,790 6870 0.8 5,000 5496 8 1/2" 7" 8,475 6,922 7240 0.8 5,000 5792 Max Anticipated Surface Pressure MASP=Lessor of(Frac Pressure @(0.052 X(MW+0.5ppg)X TVD)-GasGRD X ND))or(Max Pore Pressure-(GasGRD X ND)) Frac Hole Sizes Casing Size Max EMW Frac Grad at MW Safety Gas Max PP at MD(ft) TVD(ft) PreSssure hce at Next TVD MASP(psi) 1m' 1 (in) (ppg) Shoe Factor Gradient 12 1/4" 9 5/8" 2,023 1,790 8.9 15.2 0.50 0.10 1282 2,511 1,282 8 1/2" 7" 8,475 6,922 9.8 15.8 0.50 0.10 5175 3,527 3,527 Max Allowable Surface Casing Pressure MASCP=(0.80 X CASING BURST)-(MW-Pore Pressure)X.052 X ND Max EMW Hole Sizes Casing Size MD ftTVD ftBurstSafety ( ) ( ) (psi) MW (Pore MASCP i (in) (in) Factor (psi) Pressure) 12 1/4" 9 5/8" 2,023 1,790 6870 0.8 9.2 8.9 5468 8 1/2" 7" 8,475 6,922 7240 0.8 9.8 9.8 5792 BOPE: Annular/VBR/Blind/Kill Line/VBR Wellhead: 5,000 PSI Vetco Gray 9 5/8" slip on weld with 11"top Drilling rig: Patterson 191 Engineer Contact information: Courtney Rust, Drilling Engineer Email: courtney.rust @ cookinlet.net Phone: 907-433-3809 Variances requested: AOGCC Regulation 20 AAC 25.235 Gas Disposition CIE requests permission to vent or flare gas from the Olson Creek2 well test for a period of 14 days according to 20 AAC 25.235 d(6). Maximum anticipated daily flaring is expected to be 1MMSCF/D with a total expected not to exceed 10 MMSCF over the entire test. • AOGCC Regulation 20 AAC 25.265 Automatic shut-in equipment a well that is capable of unassisted flow of hydrocarbons to surface and that has an onshore surface location that is 660 feet or less of (A) a permanent dwelling intended for human occupancy, including a billeting camp or private residence; (B) an occupied commercial building, excluding a structure located within an existing oil or gas field; (C) a road accessible to the public; (D) an operating railway; (E) a government maintained airport runway; (F) a coast line measured at mean high water; (G) a public recreational facility; or (H) navigable waters as defined by the United States Army Corps of Engineers in 33 C.F.R. Part 329.4 with boundaries defined in 33 C.F.R.329.11; The Olson#2 exploration well is located on a logging type road which is not considered as public access. Cook Inlet Energy does not intend to install a SSSV should the well be completed and requests confirmation from the AOGCC that it would also not consider the well road as a public access way • 0 Procedure: 1. Test BOPE 2. Set EZSV @8410' and down squeeze 6 bbls of cement and dump 3 bbls on top. 3. RIH with bit and scraper to top of cement 4. Run CBL. Squeeze if necessary - --' T'CC1 0-G ti4 '"" 5. Change over to filtered 4% KCL brine. Filter to 20 ntus. 6. PU TCP guns and RTTS packer assembly C9. RIH on 4" DP Short fill DP for a 500 psi underbalance PU guns to firing depth and set packer Test backside to 1000 psi. Leave pipe rams close. . Check correlation with GR-CCL 11. RU test tree and test spread. 12. Test equipment and lines to 5000 psi. 13. Pre-test safety meeting. 14. Drop bar and fire guns 15. Test well according to Reservoir Engineer 16. Unseat packer and circulate well dead. 17. Check for flow and POH. • • • Olson #2 Plan Forward 1. Test BOPE - Complete 2. M/U EZSV cement retainer for 7", 29# P110 casing, RIH on 4"DP and set retainer at 8,410' - Complete 3. Un-sting from retainer. - Complete 4. Pump 10 Bbl Water Followed by - 9 Bbl Cement Mixed to 15.8ppg Followed by 3Bbl Water - Displace cement 10Bbl Short of EZSV (Put 5 Bbl Water in Annulus) - Stab into Retainer- Squeeze 5Bbl Water+ 6 Bbl cement Below EZSV. Dump 3 bbls cement on top of retainer. - Complet �' 5. Pull up2 stands and reverse out. - Complete (0');:ii%";- �f�f�� p vrlyell'16. RU eLine and run CBL. Rig Down eLine �� 7. RIH with bit and scraper to top of cement. Filter 4% KCL to <20 NTU 8. Change over to filtered 4%KCL brine. Filter to 20 ntus. 9. POH Test Zones \[A 8190'-8230' Ji B 7980'-8015' C 7470'-7580' 10. PU TCP guns and packer assembly for Zone C 7470' to 7580' 11. RIH on 4" DP Short fill DP for a 500 psi underbalance 2. Set guns 15' below firing depth. 13. PU guns to firing depth and set packer 14. Test backside to 1000 psi. Leave pipe rams closed. 5. Check correlation with GR-CCL 16. RD wireline. 17. RU test tree and test spread. 18. Test equipment and lines to 5000 psi. 19. Pre-test safety meeting. 20. Drop bar and fire guns 21. Test well according to Reservoir Engineer 22. Unseat packer and circulate well dead. 23. Check for flow and POH. 24. If Zone C test is negative, Repeat steps 10 through 23 for two lower zones. • Olson Creek#2 Current Wellbore 9-25-14 t` r ': 1 /8" L80 117'TVD i'} . 68# BTC 117'MD $M �1 Y 12 1/4"Hole 9 5/8" L-80 1,790'TVD 40# BTC 2,023'MD ►+: IVA 64 8.5"Hole 1` '6P' 7" L80 1,699'TVD 41 26# DWC 1,883'MD 7" P110 6,922'TVD 29# DWC 8,475'MD L Yt. 6 1/8"Hole 9,657'TVD 4..... 11,589'MD Olson Creek#2Proposed Wellbore 9-25-14 20" L80 117'ND 133# BTC 127'MD Planned Perforations 7470'-7580' It. 12 1/4"Hole 7980'-8015' 41 thi, 9 5/8" L-80 1,790'TVD 8190'-8230' 47# BTC 2023'MD V 8.5"Hole 6,927'TVD 8,480'MD ..s Top of Cement @ 8,360' /� Top of Retainer @ 8,410' _ ;- 7" L80 1,699'TVD ? •4..' • " ' s 26# DWC 1,883'MD olr-1 '1a �.,t `� ,' ,. , 7"Shoe 7" P110 6,922'ND r:+t 29# DWC 8475'MD Bottom of Cement @ 8,575' ''� :1 'x' 6 1/8"Hole 11,589'MD —t, 9,657'TVD i • Wellhead Schematic — note tree not in place M GE Oil &Gas I. .,r (LI )I 'az srlrr 1 = Ma Vim' swrr ' _S♦ 1 a a itijo• ... 24116911/ I 2ILIr MO 011.-0,1,..„14 ...p.-ul u. 4t? 2a7re14 ! '' : .124r ` INA 11-em _••— 1 ,_—..- ill. —1W. Mrra Ailf 19 Cr : a Mk[N171 1 11'pN 1. 1 11/1.1111Ra :•1�� I I N MMI MVO 21 Pr il IF. Y�y x-vlrr 7 a.•Oci Imo vre MAP OM& r Coin. 1/4o. Lr. 1/P Coiled W" ALL DIMENSIONS ARE APPROXIMATE TM domino r P.properly ofGE 01 a O..Preemie Coned LP end r considered m.aideMel Mae oa eiwiee.pp.o.e r..uc. COOK INLET ENERGY,LLC ..w.r 1 nor Cc o<arts...r be toed copied,pa.rrla.e o...potsoeu t for the ae polpo..daE Oil&oini Peewee Cored LP OLSEN#2 9-5/8"x 7"x 2-7/8"5M SH2 Conventional Wellhead Assembly, °RA`"" CR 49JUL14 With T-M40-CCL TubingHanger and Adapter Flange FOR RF KN 09JUL14 9 P 9 FOR RPFERENCE ONLY DRAWING NO. 1001348 II # BOP & Diverter Sketch Operator: ('IF; Patters on17f'1Rig No.191 Date: 4-Jun-13 1111=11111.111 _ AW M . I . Component Height" Annular 49.25 Double U 66.67 Drlg Spool Al-36" ' Single U 41.69" Total: 193.61" Cameron D 1 (Top of 13 5/8"5M x 1014 I)S A=GL) 13-57'1 Cameron U wwwwii �// �^�' "---, r = 3112"x5"VBR Y•: 3-1/16",10M,K ill Line r ,.. 2 Blind/tarns Fire lt tedHase " , ��. A :: .�A M 1 Cross has 4-1116",10M Dull t r 13-5/8"10M r i i * • I 4-1/16",10M,Ki11 Line Fire Rated llose lig f lila H 13.5/8'10M 3-1/16",10M GOO/Alves Cameron U \\\ 4.1/16"HCR Gate Valve 3-1/16",10M x 4-1/16",10MDSA 4.1116",10M(ate Valve il !� ,ll31/2"x5"VBR 13-5/8"1c I .15M x M 1 i - -- 1 :_t_1,..! ., ,1 4--L---- 2-1116",5M,Gam Valve T (' flt ri, _ 2.1116",SM,(iatcValvo (L it -, : PATTER`' ON-VTI TYPE E - 10M Choke Manifold Well Control c It -alit OMR i ii Ma= , I J , MM. ,3 \1 i. = I -�: : ',:,'te,.. D. ;ii‘ ,: ,; i z _ 0 0 0 0 Q 0 PM-334 4 1/16"10M Manual Gate Valves 4 1/16" 10M Manual Choke Valves Valve® thru 0 TYPE Cameron. Valve® and e TYPE Cameron. 2 1/16"10M Manual Gate Valve 31/16"1OM Wits M-3 Remote Choke Valve® TYPE Cameron Valve® TYPE Cameron. 0 i Ui- 2 w J 11 'F:2) �- § xC I a of wE 1 ----m® Ell-- mm i i n I I I its - Z I) 0 ID h. ID rb___ ilD a . Pe a tit] ; i ; eix 1k0a I • M \Z f 111 �� i o 'o i1 i ; 1 HH1 li . ilii 1111 i h I i I L— — — —— — —— — — — — — —— -i r g o s §4. I d I %w i /. 1 o I • Schwartz, Guy l (DOA) From: Schwartz,Guy L(DOA) Sent: Tuesday,September 30, 2014 8:23 AM To: 'Conrad Perry' Cc: Courtney Rust; Evan Harness; Bettis, Patricia K(DOA) Subject: RE:Olson 2 PTD 214-113 6 1/8" hole abandonment and DST Sundry application Conrad, Verbal approval granted to test well as proposed in your sundry application. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Conrad Perry [mailto:Conrad.Perry©cookinlet.net] Sent: Monday, September 29, 2014 1:58 PM To: Schwartz, Guy L(DOA) Cc: Courtney Rust; Evan Harness Subject: Olson 2 PTD 214-113 6 1/8" hole abandonment and DST Sundry application Guy, Cook Inlet Energy requests verbal approval to Drill Stem Test Olson Creek#2 in accordance with the Sundry Application submitted today, Monday September 29, 2014. We should be in a position to test the well tomorrow, necessitating the request for a verbal. conrad Drilling Manager Cook Inlet Energy, LLC 601 W. 5th Avenue STE 310 Anchorage, AK 99501 (907)433-3816—Office (907)727-7404-Cell (907)344-0584- Home (907) 260-5356-Cabin conrad.perry@cookinlet.net CONFIDENTIALITY NOTICE:This e-mail transmission and any document,files or previous e-mail messages attached to it,are confidential. If you are not the intended recipient,or a person responsible for delivering it to the intended recipient,you are hereby notified that any review,disclosure, copying,dissemination,distribution or use of any of the information contained in,or attached to this e-mail transmission is STRICTLY PROHIBITED. If you have received this transmission in error,please notify us immediately by forwarding this message to the original sender or by telephone at 907.433.3816 and then delete this message and its attachments from your computer. 1 • From:Schwartz,Guy L(DOA) (mailto:guv.schwartz@alaska.gov] Sent: Monday,September 29,2014 1:44 PM To:Conrad Perry Cc:Courtney Rust; Evan Harness Subject: RE:Olson Creek Test Head.xlsx Conrad, You will need to request by email verbal approval to flow test well. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Conrad Perry [mailto:Conrad.Perry©cookinlet.net] Sent: Monday, September 29, 2014 1:24 PM To: Schwartz, Guy L(DOA) Cc: Courtney Rust; Evan Harness Subject: Olson Creek Test Head.xlsx Guy, Please find attached our surface DST tree diagram. conrad 2 • • COOK INLET ENERGY OLSON CREEK#2 WELL Sep-14 DRILL STEM TEST HEAD FULL OPENING SAFETY VALVE • EMERGENCY SHUT DOWN VALVE WITH TWO REMOTE STATIONS FULL OPENING SAFETY VALVE • I 14/ TO CHOKE MANIFOLD monon, AND TEST SEPARATOR 1502 BALL VALVE FULL OPENING SAFETY VALVE • ROTARY TABLE 110 • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Thursday, September 25, 2014 3:05 PM To: 'Conrad Perry; Ferguson,Victoria L(DOA); Bettis, Patricia K(DOA) Cc: Courtney Rust;Stephen Ratcliff; Evan Harness;Tyler Wagner; Greg Kirkland;Art Saltmarsh Subject: RE:Olson 2 PTD 214-113 6 1/8" hole abandonment Conrad, We have reviewed the OH logs and agree there are no significant hydrocarbon zones in the 6 1/8" hole section. You have approval to plug off the lower section as proposed using a retainer and pumping volumes to meet the requirements of 20 AAC 25.112 (b)(2). Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Conrad Perry [mailto:Conrad.Perry(acookinlet.net] Sent: Thursday, September 25, 2014 2:25 PM To: Schwartz, Guy L(DOA); Ferguson, Victoria L(DOA) Cc: Courtney Rust; Stephen Ratdiff; Evan Harness;Tyler Wagner; Greg Kirkland; Art Saltmarsh Subject: Olson 2 PTD 214-113 6 1/8" hole abandonment Guy, We have just TD'd Olson 2 and have found no hydrocarbons in the 6 1/8"hole section. Our intent is to abandon the 6 1/8"hole section by setting a cement retainer 25' into the 7" shoe and down squeezing sufficient cement to cover 100' of open hole below the retainer. We would then dump 50'of cement on top of the retainer. I have attached all LWD and Mud logs for this hole section as well as the directional survey,current and proposed well bores. We intend to submit a sundry application to perform some DSTs in the 7"hole section. Please advise if this is acceptable. conrad Drilling Manager Cook Inlet Energy, LLC 601 W. 5th Avenue STE 310 Anchorage,AK 99501 1 +, Database File: cieolsoncreek ..db Dataset Pathname: OlsonCree/2/runCBL1/passl9 02/Li — 1 1 3 Presentation Format: cbl_drs Dataset Creation: Sat Sep 27 14:29:59 2014 by Log SCH 120430 Charted by: Depth in Feet scaled 1:240 _R 500 TRAVELTIME (usec) 150 0 AMP AMPLITUDE (mV) 20 200 VDL 1200 9 Collar Locator -1 0 AMPLITUDE (mV) 100 0 Gamma Ray (GAPI) 150 ilt i 3 ..i; , s 111111 ■■ II■ ll6400 . .„., E ■■tI . 1 id.___ . 1_ ,_, s.3 ,.,..■ ll, . :,,ii. , 'Egli [i 11111111 j -44. ,, : ;., „ ....,i_ IIi !tii_ � 64 50 min 1'+ 0 ■■ - ■ ■■■ MU !s 1 -.4. 4 : MEI ill IIIIIIIII 6500 mil I ,..:„<„,,,. . 1 e�' saii.‘3- ■ 1111141 I ll 111 Isumommuto Iill I 11 b. 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I il4'',•_ .:.' 8250 11 � �'� i ----- --M ------y!--- 111111111•111111111111111111111r. E__ -��14--_ _� --- -- -- MNIir.�=.15!1111--- 1 t, _ illiiiiii MEIME-7-701106--1111 -•,..r . ,1'.: `. 6y� ----1♦-I—�g.-- te - 1♦�1♦1♦��:i�� V. , ,r 3 'a --111.110):��—.JAM—111111 ��/MININIMI=.rr��---- � , z -�m------ f 9 k 1♦_`�r'1♦--- 3 -, rim-----7 .7,-. * t' r 8300 r=__®___ —1=1=11111111/22111•11.111•1 _—S1__—_—_7___— 4 ��' +b --/2'� — — �7— ==1--� I 1:ii-,14*,a a Ilkill immosaummummemiumumba= i 4 . ' - - $ - —t4-----i1� 4, ” c 5.1 5 lb-1- Q yrs/AA i S Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Tuesday,September 30, 2014 4:01 PM To: 'Conrad Perry' Subject: RE:Olson 2 PTD 214-113 6 1/8" hole abandonment and DST Sundry application Yes thanks. It was in the body too. Under the variance request on about page 6... Stated 1MMSCF/D and 10MMSCF total there thus our confusion. 40MMSCF is acceptable... hopefully there will be enough gas to make us push that limit. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Conrad Perry[mailto:Conrad.Perry@cookinlet.net] Sent:Tuesday, September 30, 2014 3:46 PM To: Schwartz, Guy L(DOA) Cc: Courtney Rust; Evan Harness; Bettis, Patricia K(DOA) Subject: RE: Olson 2 PTD 214-113 6 1/8" hole abandonment and DST Sundry application Guy, CIE requests permission to vent or flare gas from the Olson well test for a period of 14 days according to 20 AAC 25.235 d(6). Maximum anticipated daily flaring is expected to be 10 MMSCF/D with a total expected not to exceed 40 MMSCF over the entire test. We didn't put it in the body of the Sundry, but it was in the cover letter. Will this suffice? Conrad From:Schwartz,Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent:Tuesday,September 30,2014 3:05 PM To:Conrad Perry Cc:Courtney Rust; Evan Harness; Bettis, Patricia K(DOA) Subject: RE:Olson 2 PTD 214-113 6 1/8" hole abandonment and DST Sundry application Conrad, Can you clarify the gas venting request. What is your max day rate and total volume for the 14 day period. There are two sets of numbers in the sundry. Guy Schwartz Senior Petroleum Engineer 1 pig Regg, James B (DOA) 'Z ly I13O From: WestMac DSM <WestMacDSM@cookinlet.net> Sent: Saturday, September 13, 2014 4:22 PM To: DOA AOGCC Prudhoe Bay Cc: Regg,James B (DOA) Subject: Report BOPE Use to Prevent the Flow of Fluids from Well Attachments: Report BOPE Use to Prevent the Flow of Fluids from Well.docx Regards, CIE DSM's Allen Lunda westmacdsm(c�cookin let.net 907-433-8967 • Report BOPE Use to Prevent the Flow of Fluids from Well Report: Date and time BOPE used: 9-10-14, 10:30 AM Well: Olson Creek#2/ Beluga Point/PTD 214-113 ✓ Rig Name: Patterson 191 Operator Contact: Cook Inlet Energy, Conrad Perry Operations Summary: We were tripping in the hole after coming out for our weekly BOPE test which was witnessed by Lou Grimaldi. We had filled pipe at shoe at 2023' and had run in to 4500'where we had some restriction and screwed in to fill pipe and circulate. Driller pumped away approximately 20 bbls of mud from being packed off. When it was noticed drill pipe was bled off and shut back in. Drill pipe pressured up and annulus was flowing. It was believed to be ballooning from the pressuring up on formation but I decided at that time it would be best to shut in and circulate out in case it was a gas influx. We circulated out using drillers method. Shut back in and no recordable pressures. Circulated another bottoms up conventionaly with no gas show. BOPE Used: Hydril and #1 remote choke BOPE was used as precautionary method to assure if it was gas that there was well control. Action: Hydril and choke to be tested at first opportunity out of hole. We are currently out of hole rigging up to run 7" casing and will be testing the equipment used at that time along with the 7" rams installed. Date:9/13/14 at 16:00 hours. Allen L. Lunda DSM/CIE �G \ 9\je11, �1'io I made an initial report via an Email to Mr.Jim Regg and was informed of the proper process of reporting which I am doing at this time. I apologize for the lateness of my reporting. r • o/s©►i Cv- P1t 2-141130 Regg, James B (DOA) From: WestMac DSM <WestMacDSM@cookinlet.net> 7115/ Sent: Friday, September 12, 2014 2:05 PM ` ( To: Regg,James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Subject: BOPE Test Report Attachments: Olson Creek 2_Diverter System Inspection Report_8-26-2014.xls; BOP Test09032014_ 0002.pdf; BOP Test09032014_0001.pdf; BOP Test09032014.pdf; 9-9-14 Patterson 191 BOP Test Report Olson Creek#2.xls; 9-09-14 Patterson rig 191 Olson Creek#2 BOP Test.pdf; 9-3-14 Patterson 191 BOP Test Report Olson Creek#2.xls Mr. Regg, I hope I have captured all the reports that you are missing. Sorry for any confusion. Allen Regards, CIE DSM's Allen Lunda/ Mike Grubb westmacdsm(a�cookin let.net 907-433-8967 1 • • , STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: jim.regq at alaska.gov AOGCC.Inspectors aC�alaska.gov phoebe.brooks(a�alaska.qov Contractor: Patterson Rig No.: 191 DATE: 9/3/14 Rig Rep.: Gary Christensen Rig Phone: 9074338973 Operator: Cook Inlet Energy Op. Phone: 9074338967 Rep.: Dmitry Smushkov E-Mail westmacdsm(a�cookinlet.net Well Name: Olson Creek#2 - PTD# 2141130 - Sundry# N/A Operation: Drilling: Workover: Explor.: X Test: Initial: X Weekly: Bi-Weekly: Test Pressure (psi): Rams: 250/5,000 - Annular: 250/3,500 - Valves: 250/5,000 'MASP: 4314 ' MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen. P Well Sign P - Upper Kelly 1 P • Housekeeping P - Rig P - Lower Kelly 1 P PTD On Location P - Hazard Sec. P - Ball Type 1 P " Standing Order Posted P Misc. NA Inside BOP 1 P FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 none NA Trip Tank P - P - Annular Preventer 1 13 5/8 X 10K P - Pit Level Indicators P P #1 Rams 1 2.875x5 10k P - Flow Indicator P • P - #2 Rams 1 Blind P - Meth Gas Detector P P - #3 Rams 1 2.875x5 10k - P H2S Gas Detector P P #4 Rams 0 None NA MS Misc 0 NA #5 Rams 0 None NA #6 Rams 0 None NA Quantity Test Result Choke Ln. Valves 1 4 1/16 10k P - Inside Reel valves 0 NA HCR Valves 2 4 1/16 10k ' P - Kill Line Valves 1 4 1/16 10k . P Check Valve 0 None NA ACCUMULATOR SYSTEM: BOP Misc 1 3 1/16" 10k P Time/Pressure Test Result System Pressure(psi) 3000 - P . CHOKE MANIFOLD: Pressure After Closure(psi) 2000 - P Quantity Test Result 200 psi Attained (sec) 12 P No. Valves 11 P - Full Pressure Attained (sec) 88 P Manual Chokes 2 P - Blind Switch Covers: All stations Yes Hydraulic Chokes 1 P . Nitgn. Bottles Avg. (#and psi): 4 @ 2,500 PSI P - CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures: 0 ' Test Time: 7.0 Hours Repair or replacement of equipment will be made within 0 days. Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Remarks: AOGCC Inspection I ,t 24 hr Notice Yes Date/Time 8/28/2014/12:26 Si - 9115/14" Waived By Jim Regg Test Start Date/Time: 9/2/2014 18:00 (date) (time) Witness Test Finish Date/Time: 9/3/2014 1:00 Form 10-424 (Revised 06/2014) 2014-0903_BOP_Patterson191_OIsonCk-2.xlsx • • 7 .1P--- • • t i / �---- _ .- __. —_- x55_\-4 �, 4.,'� 9,�a _ 4 , • '- '-',' ,--<.".---'r---t- ,--111-.---,:-d---- "--- 7_-_- -_______„:„.4s00 -.w,-- ____„,„„„,.... 41,N, 0001 .'.';'.-",-- -->-••------ , --;:-A---"-- ' - -----:-1:41:-___)-•----3-41;" !it441"%, ifttle,ragb A4111 moi F �- -- -50°', 'i -rte ---.--::\--:."2--:-_--- --_ AVW �o'� ` O J o , , ,) j ,, _ JOOQ ■. 2500 �-% ;< '">)-C1-1: -\-:::- :'':'\< � \ • 2000 Q � • apo ..t. < '„.,,..,„,,,,-.,/./,,,., ;;,7 \. '4 • \ \ *WS: ��it. %� ‘ ��0 A lye --- - 4.4114,* ........r, 11/4 ‘ ,, ,,,, ,\.,,, i _5,_..- , ..„, it,.. 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't- ---: - - - Eiilliki4441,4s, -- ..-. -- ----- _:L--- --...-__- ,„---1,',-.,'''.-'-'--,•:-?:' v ' : ' .---'----- . • 9 80P rt r 09/02/1 agrit ,'Zf Vowed./vote 250 goal 5 sriKe 5000 44 5 We 7S#2-C,o1e prariAi cave 4 7, 9,& 10, etara'io ataahe, &/ray /dap 250 bow 5 wire 5000 44 5 or/ire 77;57-13--0014 ara4i fig ashes 1, 1, 7, 8, & 11, &vomit.Paan 250 foal 5#48 5 40 5 oat Trer#4-C 4'/. aaIaee 2, 3, &5, Mc' &LII//A°250 hal 5 KA? r-is_eae tYCiP&itIaraa#oa�rw 250 foal 5 Sae 5000',( 4 5 oriKB 7 #6-C%.6 nroaaf&dao`t aafre 250 low 5/trio 5000 44 5 oriKB 7S#7-11/Orafah 250 low 5 ohm'3500 4% 5 wire 7 S7 #8-Blind pore 250 kw 5 mire 5000 44 5 mho rsr#9-1000 pi koro teat or all twee aAo 1000 pti 5 mho #10 f4aaaorafatoi"war testa -pod 'aro C/ %8te�ree S . ! Accumulator Function Test Step#1 TO CHECK THE USABLE FLUID STORED IN THE ACCUMULATOR BOTTLES ON THE ACCUMULATOR 1. Make sure all rams and annular are open and if applicable HCR is closed. 2. Ensure accumulator is pumped up to working pressure!(Shut off all pumps) 3. Open both HCR's. 4. Close Annular. 5. Close Upper and lower Pipe Rams. 6. Open one set of the pipe rams to simulate closing the blind ram. 7. Accumulator pressure should be 200 psi over desired precharge pressure.(1,200 psi minimum) Record the remaining pressure /WO psi.Do apt bleed this pressure off. For next step.Start with this remaining pressure. Step#2 TO CHECK THE CAPACITY OF THE ACCUMULATOR PUMPS 1. Turn both electric pumps on.Record the time it takes to pump up 200psi from the remaining pressure from Step#1 AZ— seconds. 2. Simultaneously when you reach the 200psi turn on both air pumps.Record the time it takes to pump up to full operating pressure ,Sif seconds.(We average 90 seconds.Should not exceed 4 minutes) Nitrogen Back up Pressure: Bottle 1 = 255e9 psi/Bottle 2=14ee psi/ Bottle 3=ikoo psi/Bottle 4= ,TSS 00 psi • Pm Z141I13o Regg, James B (DOA) From: Evan Harness <Evan.Harness@cookinlet.net> Kg ,,r1 Wednesday, October 08, 2014 1:09 PM �`I. 10 ti14 To: Regg, James B (DOA) Subject: Olson Creek#2 PTD 214-113 Attachments: Olson Creek PTD # 214-113 10-08-14.pdf; ATT00001.htm 1 • S Wednesday, October 8, 2014 Olson Creek #2 PTD 214-113 Mr. Reg the summary of out Olson Creek # 2 Abandonment are Below - Operations went as Planned to the Point of pressure testing the Surface Plug prior to Nipple Down of BOP - The Cement Used for the Top Plug took forever to Set Up - I will call after sending this to Make Sure AOGCC are satisfied with our Efforts - Our Intent is to Move the Rig Off and then Recover the Wellhead and Weld on Abandonment Plate OUTLINE ABANDONMENT PROCEDURE Unset Tcst Packer Done 2. -Changeover to 9.5 ppg mud circulating over choke Done 3- Check for flow, POH. Done top perf) Done 5. Set Retainer and establish injection rate Set EZSV Retainer - Set 25,000# Pipe weight Down - Pressure Tested to 2,500psi 6. Squeeze minimum 9 bbls 15.8 ppg cement (225 linear feet of 7") below retainer, leave 3 bbls cement on top. Squeezed 10BbI Below - Equalized 5Bbl on top 7. Pick up 3 stands and circulate clean. Test Casing to 500 psi above injection pressure Pressure Tested to 2,500psi 5Uupsi over fina injection Pressure 8. POH. Pressure Tested Casing and Abandonment Plug to 2,500psi for - 30min 9. Rig up eLine and punch 8 holes in 7" casing at 300'. Pressure up on 7" to ensure holes are clear. Set Bridge Plug at 310 - Pressure Tested to � L N„ Punch Holes in 7" at 301 10. Pick up 5" drill pipe and space out to 5' below wellhead. Close pipe rams. ,igged up on 7" Annulus Valve - Took Returns on 9 5/8 by 7" - Annulus Valve 11. Circulate 7" x9 5/8" annulus clean. Cir and Pumped around 20BbI Fresh Water • S Wednesday, October 8, 2014 Olson Creek #2 PTD 214-113 12. Circulate 15.8 ppg cement down drill pipe taking returns out 7" x 9 5/8" annulus. Jean Cement to Surface with 22Bbl Pumped - Pumped a total of 27Bbl with 6Bbl clean Cement to Surface 13. WOC. Tag cement. This is where we had trouble - We used a cement that was Blended for 7,500' with Cacl added - Not the Smartest thing I have done (took Forever to set up) - WOC 16hrs - Attempt to Pressure test 7" Surface Plug Would not test - Quick Pressure up (Less Than .5Bbl) to 1,000psi -Slow Bleed off to 700psi - WOC 22hrs Attempt to Pressure test - Quick Pressure up (Less than .5 Bbl) 1,300psi Slow Bleed to 800psi - Attempt Pressure test of 9 5/8 by 7 Quick Pressure up (Less than .5 Bbl) 1,000psi - Slow Bleed off to 700psi - Tag Cement in 7" at 42' 16' below Wellhead - Mobe BJ for Re-squeeze - Could not establish any Injection with 1,800psi - Re-Tag Cement in 7" at 42',16' Below Wellhead -Attempt to Wash Down 3.5BbI/min - Could not wash Down - Cir Cement to 7" Annulus Valve - Shut CSO Rams (Blinds) - Apply 1,600psi squeeze pressure and hold same 3hr Very Slow Bleed off to 1,300psi - Fill 9 5/8 by 7 with .25Bbl Cement till cement returns at 9 5/8" Ann Valve - Pressure to 1,500psi and Hold 3hr Slow Bleed to 1,200psi - Bleed off Pressure - WOC 2hr - Pressure test 7" to 1,600psi for 30 min - Pressure test 9 5/8 by 7" to 1,500psi for 30min - Charts Attached 14. Nipple down BOPs. 15. Release rig for move. Guy, Cook Inlet Energy requests verbal approval to abandon Olson 2 in accordance with 20 AAC 25.112. Per our discussion we will down squeeze sufficient cement below a retainer set at 7,455' to cover 100' of 7" below the bottom perf at 7580'. We then plan to punch holes in the 7" casing at 300' and circulate cement into the 9 5/8"(surface casing) x 7" annulus, leaving cement inside the 7" to just below the wellhead. The following is an outline procedure and I have attached a proposed abandonment sketch. We are currently still flowing, but will start pulling out of hole shortly. Wednesday, October 8, 2014 Olson Creek #2 PTD 214-113 OUTLINE ABANDONMENT PROCEDURE 1. Unseat Test Packer 2. Changeover to 9.5 ppg mud circulating over choke 3. Check for flow, POH. 4. Pick up cement retainer and RIH on drill pipe to 7455' (15' above top perf) 5. Set Retainer and establish injection rate 6. Squeeze minimum 9 bbls 15.8 ppg cement (225 linear feet of 7") below retainer, leave 3 bbls cement on top. 7. Pick up 3 stands and circulate clean. Test Casing to 500 psi above injection pressure 8. POH. 9. Rig up eLine and punch 8 holes in 7" casing at 300'. Pressure up on 7" to ensure holes are clear. 10. Pick up 5" drill pipe and space out to 5' below wellhead. Close pipe rams. 11. Circulate 7" x9 5/8" annulus clean. 12. Circulate 15.8 ppg cement down drill pipe taking returns out 7" x 9 5/8" annulus. 13. WOC. Tag cement. 14. Nipple down BOPs. 15. Release rig for move. conrad Drilling Manager Cook Inlet Energy, LLC 601 W. 5th Avenue STE 310 Anchorage, AK 99501 (907) 433-3816 — Office (907) 727-7404 - Cell (907) 344-0584 - Home (907) 260-5356 - Cabin • • Wednesday, October 8, 2014 Olson Creek #2 PTD 214-113 Schwartz, Guy L (DOA) RE: Olson 2 PTD 214-113 Abandonment October 3, 2014 at 9:31 AM Conrad Perry Courtney Rust , Evan Harness Bettis, Patricia K (DOA) Conrad, Verbal approval granted to P & A Olson #2 as proposed below with below modifications: 1) Pressure test and chart casing against lower retainer after dumping cement. (1500 psi min) 2) Cut off wellhead 5' below GL per 20 AAC 25.112 (d) and weld plate per 20 AAC 25.120. 3) Notify inspectors to witness. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office This email confirms your request for an inspection with the following information: Type of Test Requested: P &A Requested Time for Inspection: 10-06-2014 7:00 AM Location: Patterson 191, Olson Creek#2, Beluga • • Wednesday, October 8, 2014 Olson Creek #2 PTD 214-113 Name: Dmitry Smushkov E-mail: westmacdsm@cookinlet.net Phone Number: (907) 4338967 Company: Cook Inlet Energy Other Information: Mr. Regg, We are plugging and abandoning Olson Creek#2. We plan to have our top plug in place by Monday 10/06/2014 07:00hrs. Please let us know if you have any questions. Thank you for your time. If you are not contacted within 12 hours, please notify Jim Regg at 907-793-1236. Thank you! Alaska Oil and Gas Conservation Commission • • • Olson Creek#2 Abandoned Wellbore 10-08-14 7"Csg punch @ 301' • ..t.: ' .... • ' L Cast Iron Bridge Plug at 310 _ 20" L80 117'TVD 133# BTC 127'MD 12 1/4"Hole 4 9 5/8" L-80 1,790'TVD 5bbl Cmnt on top of Retainer 47# BTC 2023'MD Cal Top 7,320 — i _ Top of Retainer @ 7,455' Perforations 7470'-7580' 8.5"Hole 6,927'TVD 10.6 bbls cement below retainer 8,480'MD (Cal Btm 7,735) Top of Cement @ 8,360' Top of Retainer @ 8,410' C7" L80 1,699'TVD 26# DWC 1,883'MD a • 7"Shoe 7" P110 6,922'TVD „ 29# DWC 8475'MD Bottom of Cement @ 8,575' , 6 1/8"Hole 11,589'MD – - 9,657'TVD • r ' 8 J � nr, _,_� 00 :Z550mitro `` 5000 .x= , 000•••••• ift, �I - �h 114 4 �� i� .' 4000 a� c� y/ - 3500 �"� �►is I ��I % � 3000 ' 7 '/ I / oo .. , �� ,� �".4404° =_ 0 . 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N.* 4'llefg7".*61 1. - -foi, - ,•\ ,%. , ,4*...!........:::, i . 4. „.0 Isikts„ N,‘4 '''4 _V ,e. 4k.-N, ** N. • .„ .. _ . ; ,, --:-;,...704:0:14a,00.00 , is> 4414% .4144:441;„0, ,,„,,„, oose amiusull" 4stv 4iiiZro 000P inr4._ a"..:11 .1.1.1.100re 4°'1- °009- - •••• 00.w.•••••046 6 nnn--`-`-----.�. --_ - ,/'� OF 1' • \\I%%% tss 1' I J 1�ri�' ' A.i a..r.E e GU and, C a„s; 7 _ 333 West Seventh Avenue GOVERNOR SI-AN PARNI7T Anchorage, Alaska 99501-3572 rw,y Main: 907.279 1433 C7 275 Int% Conrad Perry Drilling Manager Cook Inlet Energy, LLC 601 W. 5th Ave., Suite 310 Anchorage, AK 99501 Re: Exploratory Field, Exploratory Pool, Olson Creek Well #2 Cook Inlet Energy, LLC Permit No: 214-113 Surface Location: 2629' FWL, 2735' FNL, SEC. 6, T13N, RIOW, SM Bottomhole Location: 3510.08' FEL, 1794.40' FNL, SEC. 1, T13N, R11 W, SM Dear Mr. Perry: Enclosed is the approved application for permit to drill the above referenced exploration well. All dry ditch sample sets submitted to the AOGCC must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by Cook Inlet Energy, LLC in the attached application, the following well logs are also required for this well: record gamma ray curve from base of conductor to TD along with the logging program proposed by Cook Inlet Energy, LLC and approved by AOGCC. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. 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 AOGCC 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 AOGCC's internal use. • Permit No:214-113 Cook Inlet Energy, LLC Page 2 of 2 Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC 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 an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, S Daniel T. Seamount, Jr. Commissioner v.d DATED this ZZ day of August, 2014. lb • RECEIVED AUG 192014 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 �V �� __/6v;, '_ 8/1 ��AQ CC 1a.Type of Work: lb.Proposed Well Class: Development-Oil 0 Service-Winj 0 Single Zone ❑, 1c.Spa ifyif well is proposed for. Drill O• Lateral Cl Stratigraphic Test 0 Development-Gas Cl Service-Supply Cl Multiple Zone ® Coalbed Gas 0 Gas Hydrates 0 Redrill Cl Reentry 0 Exploratory 0' Service-WAG 0 Service-Disp 0 .R,\> Geothermal ❑ Shale Gas Cl 2.Operator Name: 5. Bond: Blanket 0 Single Well ❑ 11.Well Name and Number: COOK INLET ENERGY,LLC Bond No. 61212870" 0145)LSON CREEK WELL#2. 3.Address: 6.Proposed Dep :9(,O (0004 12.Field/Pool(s): 601 W 5TH AVE SUITE 310,ANCHORAGE,ALASKA 99501 MD: 11087, ND: 40024 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): EXPLORATORY Surface: 2629'FWL,2735'FNL,Sec 6,T13N,R1OW SM MHT9300062 Top of Productive Horizor2506.30'FEL,1960.18'FNL,Sec 1,T13N,R11 W SM 8.Land Use Permit: 13.Approximate Spud Date: MHT 9300062 11141130):)(3 8/15/2014 pm, Total Depth:3510.08'FEL,1794.40'FNL,Sec 1,T13N,R11 W SM 9.Acres in Property. i � 14.Distance to Nearest Property. $3 , 3.. // 0 t(q 2,640'FNL,2,640'FEL 4b.Location of Well(State Base,;1,9,11e Coordinates-NAD 27): 10.KB Elevation above N 318 feet 15.Distance to Nearest Well Open Surface: 2649817`0 299832 lit,, Zone 4 GL Elevation above M 291.5 feet to Same Pool: N/A 16.Deviat d wells: Kickoff depth:600' feet .It 17.Mapmum Anticipated Press}pis in psig(see 20 AAC 25.035) Mapmum Hole Angle: <a- -51-degrees Downhole:S3/ 4568.92 -.1-' Surface: 4314 PSI 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) Driven 13 3/8" 68# L80 BTC 200' 0 0 200 200 - 12 1/4" 9 5/8" 40# L80 BTC 2,000' 0 0' 2,000' 1,781' 142 sxs 8.5" 7" 29# L80 BTC 8,500' 0 0 8,500' 6,961' 170 sxs 61/8" 5" 188 L80 BTC 4,767' 4,200' 5,851' 11,96T 10,024' 376 sxs 1". PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Dep, •ti i: Total Depth ND(ft): Plugs(measured): Effect.Depth MD(ft): Effect Depth ND(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface htermediate Production Liner Perforation Depth .I . Perforation Depth TVD(ft): _ 20.Attachments: Property Plat 0 BOP Sketch 17 Drilling Program O Time v.Depth Plot O Shallow Hazard Analysis O Diverter Sketch 0 Seabed Report Cl Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21.Verbal Approval: Commission Representative: Dare 22-Jul-14 22. I hereby certify that the foregoing is true and correct. COURTNEY RUST 433-3809 Contact COURTNEV.RUST @ COOKINLET.NET Email Printed Name CONRAP " -'Y Title DRLLNG MANAGER Signa Phone Phone 907-727-7404 Date 22-Jul-14 Commission Use Only Permit to Drill `' IAPINumber.. Permit Approval I 1 See cover letter for other Number. 6l - 50-a 3�al0I �f-00 -00 Date: he ( requirements. Conditions of approval: IF box is checked,well may not be used to explore for,test,or produce coaled ethane,gas hydrates,or gas contained in sh,les: gl Other. ku( 3-00 j..', 6,c,P �j Samples req'd:Yes No❑ Mud log req'd:Ye ti„ No❑ tr z L� �, r ,4n.ti.,-Ccs.^ 777-51.4"- �•7-5 7 HZS measures:Yes No�❑/ Directional svy req'd:Ye No,❑,/ �7 E-- Spacing exception req'd:Yes❑ No Of hclination-only svy req'd:YeO No 4I" /\e_ ^.. a /" c�+k,,f} r , r r tic t1.6b-ss--<f!� (1—^ 00,-,f/4-1-4-,-, St -[.�v"y. L r� � G APPROVED BY Date: (J "T elaz_ 1 (/- Approved b. / COMMISSONER THE COMMISSION ?141SS/2°/i/ 1 _ , IGINAL i 1110 411 RECE/Vet) AUG 19 2014 STATE OF ALASKA AOGQ6 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL /ij. ) �(� 20 MC 25.005 — �i 5 l r t 1 a.Type of Work: 1 b.Proposed Well Class: Development-Oil 0 Service-Wiry 0 Single Zone D 1 c.Specify if well iproposed for: Drill O Redril 0 Stratigraphic Test 0 Devebpmert-Gas 0 Service-Soppy ❑ Mtatiple Zone 0 Coabed Gas / Gas Hydrates 0 Re-entry 0 Exploratory ❑O /Service-WAG 0 Service-Disp 0 l Shale Gas 0 2.Operator Name: 5. Bond: Blanket p Single Wel ❑ 11.Well and Number: COOK t'ILET ENERGY,LLC Bond No. 61212870 „36 O ON CREEK WELL#2- 3.Address: 6.Proposed Dep : o I 0 p 12.Fi ool(s): . i's 601 W 5TH AVE ANCHORAGE,ALASKA 99501 MD: TVD: . 2a 4a. Location of Well(Govemmental Section): 7.Property Designation(Lease Number): / EXPLORATORY- Surface: 2629'FWL,2735'FNL,Sec 6,T13N,R1OW SM MHT 9300062 i / Top of Productive Horizor 2506.30'FEL,1960.18'FNL,Sec 1,T13N,R11 W SM 8.Land Use Permit 13.Approximate Spud Date: MHT 9300062 8/1/2014 Total Depth 3510.08'FEL,1794.40'FNL,Sec 1,1-13N,R11 W SM 9.Acres in Property. /' 14.Distance to Nearest Property 5483 / 2,640'FNL,2,640'FEL 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: j 318' 15.Distance to Nearest Well Open Surface: x-264980 y- 299832 Zone- 4 GL Elevation above MSL: ' 291.5, to Same Pool: WA 16.Deviated wells: Kickoff depth 600 feet• 17.Maximum Anticipated Press in psig(see 20 AAC 25.035) Maximum Hole Angle: y 7- -5ttlegreesM) Downhole: 5316 / Surface: 4314 psi. 18.Casing Program: Specifications Top-S-ttirg -Bottom Gernert Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD ND ,r'r§ MD ND (including stage data) Driven 13 3/8" 68# L80 BTC 200' 0 0 200 200 — 121/4" 95/8" 40# L80 BTC 2,000' 0 2,000' 1,781' 675sxs 8.5" 7" 29# L80 BTC 8,500' 0 8 .8,500' 6,961' 170 sxs 61/8" 5" 18# L80 BTC 4,767' 7,200' i'-•i�\\......\11,967' 10,024' 376 sxs r N 19. PRESENT WELL CONDRION SUMMARY(To be complet r edrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft): Pkrgs(measured): ` Depth MD(ft): Effect Depth ND(ft): Jul( viewed): Casing Size Cement Volume MD ND Condu tor/Structual Surface '. htermediate Production ,1 Perforation(ft): `/ Perforation Depth ND(ft): 20.Attachments: Property Plat O BOP SketchJDrilling Program r❑ Time v.Depth Plot O' Shalow Hazard Analysie Diverter Sket( 0Seabed Report 0 Drilling Fluid Program ID 20 MC 25.050 requiremerts0 21.Verbal Approval: Commission Representative: / Date 12-Jul-14 22. I hereby certify that the foregoing is true and correct / Contact Courtney Rust 433-3809 / Printed Name • ='Pry Title Drilling Manager Signetue /' Phone 907-727-7404 Date 7/12/2014 / Commission Use Only Permit to Drill u / API Nber. Permit Approval See cover letter for other Number. I l— !i Iyrh / 50-� ''-a 0/?y-00-000 Date: requirements. I Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coabed methane,gas hydrates,or gas contained in shales:❑ Other. Samples req'd:Yes❑ No❑ Mud log req'd:Yet Nd / H2S measures:Yes❑ No❑ Directional svy req'd:YeC NC // / APPROVED BY THE COMMISSION DATE: ,COMMISSIONER // 1 ORIGINAL • 0 {'N. ,,,,,,,.• -- . , I. '""° State of Alas , "ka z.- . Cook not Areawlde Sale Boundary ''' ... .",. ,- ., I. /// 11.1111M .... . ... ! ....... , rt„ii 4............., . . • ",,,-.4.1 ,,".'"...irmi....r.,... . / •---,,' --.E...,''7, "" ! -,-J-/"--4" • ...;.t,i....... .....•••••/..--- ';'• ,.-.;•1-i•-•'t i ) • ,--1--- ./. •' 1 J - .. ,I .• , '' ..-'' \ ' \ -.- / \.,-.,...,,, ...........,,f.,•,,, • ''...-1" ',,.1,...'4, '.s...ill / ,v. ... • ..„;,...„ • ...„,„. , .... , 'J• , -...;.,-,,ri,\-,,,,,',' ,./1". , ,.......„ .--"- ,. „..,... il 4 .... .7.47- / ...,..1 4 4 ' . / .., --- ... .........,S=.4wr ...., ..-- „...r . nw......-44:1_, .....__ ‘;'........./....."• it i / I E---.' .._._ ••- •' ., '''C'.--'''.-.s .,_ ':--%--.. ----- \ •........,,,,r4ii,s•,....,,,...,-„,....•.' -- ,-. li ,„, _ ... . • Kalgin Island ' 1.--i ...........,-1.,. no*LI .--1, • - ,•.1 "'"Ir....,... 9- S 4%‘,ti "N- S., dci ' 04,44", \X" .,--- •1 .v...\,‘% ro- ......i I r I I; Jj• 0 t .1 j i --Lir * Cook Inlet,Alaska FIELDS&FACILITIES , MAPPAAMERS ALASKA ' .. . - - Cr • -..... ; 1.4,11p. El I...4ftelIad sein ,...•:,......, 4- I..`,.011Pipel.< IE t...dral - Cereal.5.Mien .. .... . . . '-'4,....k._....rit;.......... ......4 ..`-...-.........=....7.7,A....... .4..n.L....',.==......:.:.......=.7=4.7.====... 1,k..C!(-i sliy/koi ci .. N .1. *7:-,. -, . • ! ' ;• :- • -.... 4 • tu It Y.- 11'4 ollg. - . tC f tea\N —I c... 41 1 0 4N t . ...., ..j r.• ..1 r.. E. .... .., ••' "I'l $ I • ....Cr. ri. '4I'''' It.- - • ' 4 ; InN Z c..i' >.= > / r eft CO. NI! j..., 1.. VI 4, r ,+it . • , -v. r .i rt‘ CO ,-,...r- iiiiiittjc, , - 4 --- . ., .6- . f ...,..,... .•,....... i•p. no••14 . t .. . , r iti ,..., : —I, ,...„ ,..... ..... trtk,r):>1 ....1 ' k .,... . . ..1 ,,- ‹..3- - -,4 'ore. ''''ftik„ —• ..,,„.. , / 1 J. . ill., -..... 1 11 l' c - ,....,..II 4ml I west • ••,•01 • a" .1. ...,...:. • ., • p,7 • i • • .,ICCil r k7 fr 0.4 ; , 4 tt - 4 . . -,..„, _ Cal ' R/2c,‘J E i I , 4 • Cook Inlet Energy_ ., AM 2014 A0300 July 22, 2014 Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill Cook Inlet Energy, LLC: Olson Creek#2 Dear Ms. Foerster, Cook Inlet Energy (CIE) hereby submits a revised Form 10-401 and Permit to Drill application for the Olson Creek #2 well located on CIE lease #MHT 9300062. This revised application contains additional information requested by the AOGCC and replaces the previous one. Also, attached are proposed wellbore schematics, MASP calculations, Rig Drawing, and a BOP configuration diagram. Patterson Rig - 191 will be used to complete this work, commencing approximately August 1, 2013. Maximum Anticipated Surface Pressure for this well is 4314 PSI. Please note waiver and permission to flare requests are located at the end of this submittal. If you have any questions,please contact me at (907) 727-7404. Sincerely, Conrad Pe Drilling Manager Cook Inlet Energy 601 W.5"'Avenue,Suite 310,Anchorage,AK 99501 (907)334-6745*(907)334-6735 fax . • Rig #191 Schematic and Pad Orientation n I S m oI' L O I Ni r i O 1 m ap+pp 1 r u t A§ 1 ; 1 D A a• I=mo to cm M1 _1 r- AF,'- "S1 m 34 _L., -----..--.,, r-, I t 1 0 0 _-- 4 Ka w 1 ; --7 It -- T 9.. T " -1,-- "1 '-': Ill 1 e ' m PM (14‘.--R '-A--' I : i I I ! al rr\)) r � ill i Y to z T t • c m A53' o$b ` � ... fillit �° m Z ?'is" — — 0 N RE6•:,125. —9. N_ EE ..mi G L E A 0. - ol vf2 80'-7" 57'-6" o czi i v 2 146'-11" 0 z 11� r a' n 2 II, • Location Plat 36 31 } / SECTION UNE NOTTO8C*.E 1 I FND BIM MON SECTION CORNER N:2631906.705 E 287287.602' a 1 SECTION 6 T13N R10W 2736 FN , ://// AS STAKED WELL OLSON CREEK NO.2 N:2842125.417' E:299874.309' LAT:81'14'45.898"W LON:161.09'10.548' NASP Z44 PAD EXPANSION ELEV:291.8 1.5((NAVD88) / 282W FWL- / OLSON CREEL(NO.1 LIMITS EXISTING GRAVEL PAD NOTES -3;\ 1. BASIS OF HORIZONTAL CONTROL:NAD83 US FEET POSITION (EPOCH 2003)AND VERTICAL CONTROL(NAVD88)IS AN OPUS %%%%%%1\71 SOLUTION FROM NGS STATIONS TSEA,AC51 AND ANC2 TO == ".?"..T7,'• ((c 0 F e14;116 ESTABLISH CP-39.THE ALASKA STATE PLANE COORDINATES NAD . I, 27 ZOIC4 IN FEET ARE: N•2849280.142 ;•*`49IH '*,i E•299747.051 NOR 7H 1 ELEV.=306.233(NAVIN%) -,--4.--",w-., %.. �5!"K*a• ....i 2.SECTION LINES SHOWN ARE PROTRACTED VALUES ADJUSTED �1� 0; Rµw .�@ TO MATCH FOUND BLM CORNER. SCALE �4 '•MMAL."7't 3. DATUM TRANSFORMATIONS(NAD93 ASPZ4 TO NAD27 ASPZ4) p 200 app hN'7';nw`"tet WERE DONE USING CORPSCONB SOFTWARE i I 118\\\\%%%...` FEET .w0w1 NEVISICee 1 COOK INLET ENERGY 0112,TM.1, Cook Inlet EnergyOLSON CREEK NO.2 4,:man - AS-STAKED SURFACE LOCATION =Alt 1b0ry NAD 27 1.0.4i0TN0. 142212 Golaa�wfr"FlP2Gi 1.1121!7'1112/T9121D ROOK PC 1M) C....�21c ►.O MOUE AL0011KA1[12A LOGTbN W:wnsa1 ► I IFAX )31was SEC.06 T13N R10W 1.tik-r "" 44142411•42610.0000.0010 "'°" "°`°°' SEWARD MERIDIAN,ALASKA 1 a 1 3 • r o Diverter Location Q 0 W CD CI Q � O tr Co CO Lu 0 0 b.0 0 _s Lri -s I. N 6 ,,. „ 1 y`'.. ��\N�0. _____:-_-,„,,,,..7-t----=� .� g.i.i___„...,,_a, \_�� ,1 i1 ii K- � - L- v. 1I ..�.• L M ® a) 0 t _� M o co O 0 Q W CO LLI ct J 0 O o "' w O 't CCS W N rY JCD O > J co W CD 0 I- 0 w Z O I- LL U) X w CO F 2 J 4 • • Cook Inlet Energy_ Drilling Procedure-Olson Creek 2 Pre-Spud 1. Stake Well Location 2. Drive 20" conductor to refusal at+/- 100'. 3. Install Mouse hole 4. Install 8' Well Cellar 5. Install 20" starting head 6. Clear and prep location Drilling General Note: Full opening Safety Valve will be on rig floor at all times with appropriate crossovers for all pipe being run below rotary table. 1. Move in and Rig Up Patterson 191. 2. Nipple up 21 1/4"diverter and 16" diverter lines, if required. Function test system prior to AOGCC witness. a. 48 hours' notice for remote operations 3. Pick up and stand back 5" drill pipe. 4. Function test diverter and witness by AOGCC. Give 48 hour notice. 5. Pick up 12 1/4"BHA: a. 12 1/4" MX-1 bit b. 8"Mud Motor with 1.22 bend c. 8" Stabilizer d. MWD w/GR e. 3 Flex Collars f. Weatherford 7-3/4"jars g. 21 Joints HWDP. 6. Clean out conductor and spud well. Note time and date in report. 7. Drill 12 1/4"vertical hole to 500' kick off point, per directional plan. 8. Directionally drill 12 1/4"hole to 2013'MD/1790'TVD. 9. Circulate Hole Clean. Check for Flow. POH. Stand back directional tools. 5 • • a. Note: If any sign of swabbing, run back to bottom immediately. b. Pump/Rotate out of hole if necessary. 10. Rig up to run 9 5/8" casing. 11. Run 9 5/8", 40#, L80 Buttress casing to +/- 2,000' with Float Shoe and Stab-in float Collar on joint up. Land casing elevators on wood blocks close to RT. a. Centralize casing i. One per joint on first 4 joints ii. One per 4 joints to conductor. 12. Make up false rotary and surface flow nipple. 13. Pick up cementing stinger and centralizer. 14. RIH on 5" drill pipe. 15. Stab into float collar. Establish circulation slowly. 16. Rig up cementers and test lines. 161 pea, G_Ly 17. Pump 12.5 ppg lead cement until returns to surface. Tail with 500' of mpg. Plan to use 100% excess, per cement program. Dump excess cement into cellar. Have cement retarder on hand. 18. Un-sting from collar and check for back flow. Drop wiper ball and circulate drill pipe clean. 19. POH with drill pipe. Rig down false rotary. 20. WOC for 12 hours minimum. a. Check for flow on both inside and annulus. b. Lift riser&make rough cut on 9 5/8" casing. c. Lay down casing stub. d. Nipple down diverter. 21.Nipple Down Diverter. Dress conductor and 9 5/8" casing. Check for cement to surface. Perform top job if cement is not at surface. Notify AOGCC.('l 41' °b L ":^-c-6) 22. Install, weld, and test Vetco 5M 13 5/8"multi-bowl wellhead. Orient to match existing wellheads on pad. 23.Nipple up and test 13 5/8" BOPE with 3 '/z"x 5" VBR pipe rams, Blinds in middle. a. Test Rams to 4500 psi L--> A/il t' /o 4`- k b. Test Annular Bag to 2500 psi. 24. Clean pits and make up new mud system. 25. Pick up and stand back sufficient 5" drill pipe if not done already. 26. Pick up 8 '/z"BHA: a. 8 '/z" PDC Bit b. 7 5/8" Mud Motor c. MN Stabilizer d. 6 V4" MWD-GR e. PWD Sub 6 • f. NM Stabilizer g. 3x63/4"NMDC h. 6 Joints HWDP i. Jars j. 14 Joint HWDP 27. RIH to 1000'. Perform shallow MWD test. 28. Continue RIH. Test Casing to 300Qpsi. Drill out float collar, shoe track and float shoe. Drill 20' of new formation. Circulate and condition mud. a. Perform Leak off test(call town if less than 12.0 ppg) 29. Directionally drill 8 ''/2" hole to 8,500' MD/6,961' TVD, per directional plan. 30. Circulate hole clean with minimum of three bottoms up. Preferred procedure is first circulation on bottom,pull a stand for the next, and same for the third and fourth if necessary. Pull out of hole. Avoid back reaming if possible. Pump out of hole, if necessary. 31. Lay down all smart iron and expedite back to Halliburton. 32. Make wiper trip if needed. 33. Rig up to run 7" casing. Change upper rams to 7" and test to 3500 psi. 34. Run 7", 26#, L80 BTC to bottom. a. Centralizer program to be as follows: i. 1 Solid body spiral centralizer every joint through planned TOC. ii. 1 Solid body spiral centralizer every 4th joint thereafter. b. Break circulation at 5000' and 9 5/8" shoe, and every 2000' in open hole. c. Note swab and surge pressures of tripping are excessive with 7" casing in 8 '/2" hole at this depth. 35. Circulate and condition hole. Reciprocate casing while circulating. 36. Rig up and test cementers. Cement 7" casing according to program. Continue reciprocating casing while pumping cement. Land Casing and Bump plugs with 3000 psi. Release pressure and check floats. a. Ensure cement is a minimum of 1000' above top of highest known hydrocarbons. 37. Set and Test 7" packoff to 5000 PSI 38. Lay Down 5" Drill Pipe. St" 39. Change and test Upper Rams to 3 1/2"x5". Test BOPE on 4" and 5"to-SON-psi/Hydril to/500 psi. 40. Pick up and stand back 4"drill pipe. 41. Pick up 6 1/8" BHA: a. 6 1/8"PDC bit b. 4 3/4" Mud Motor c. Stabilizer d. 4 3/4" MWD/Triple Combo 7 1111 e. Ported Float Sub f. Stabilizer g. 3 x 4 3/4"NM Flex Collars 42. RIH on 4" drill pipe to float collar. Test casing to 4500 psi. 43. Drill out float collar, shoe track and float shoe. 44. Drill 20' of new formation. Cir ulate and condition mud. Perform leak off test(Call a2-<, �4r town if less than i ppg). Su mit Chart to AOGCC. 45. Directionally drill 6 1/8"hole to TD at 11,968' MD/ 10,024' TVD, per directional plan. a. Note swab and surge pressures of tripping are excessive at this depth. Consider pumping out of the hole on any trip. b. This section will be almost entirely in the productive horizon. c. Note transition zones and reduce ROP when drilling through coals 46. Circulate hole clean with minimum of three bottoms up. Preferred procedure is first circulation on bottom, pull a stand for the next, and same for the third and fourth if necessary. 47. Pump out to 7" shoe or make wiper trip then POH. 48. Pick up Weatherford Triple combo memory shuttle log. RIH on rill pipe to TD. Circulate bottoms up. POH logging as directed to 9 5/8" shoe. Confirm logging run 1/ and depth interval with CIE office. 49. Rig up to run 5" liner. Change upper rams to 5" and test to 4500 psi. 50. Run 5"; 18#; L-80; BTC Liner to bottom. a. Centralizer program to be as follows: i. 1 Solid body spiral centralizer every joint through planned TOC. ii. 1 Solid body spiral centralizer every 4th joint thereafter. b. Break circulation at 5000', 7,500', and every 2000' in open hole. c. Note swab and surge pressures of tripping are excessive with 5" liner in 6 1/8" hole at this depth. d. Top of liner to be 300' inside 7" casing shoe. 51. Circulate and condition hole. Reciprocate liner while circulating. 52. Rig up and test cementers. Cement 5" liner according to program. Continue reciprocating liner while pumping cement. Bump plugs with 3000 psi. Continue pressuring up, setting Liner/Hanger-Packer,per Service Company's Procedure. Release pressure and check floats. Un-sting from liner. a. Ensure cement is a minimum of 1000' above top of highest known hydrocarbons. 53. Circulate out excess cement. 54. POH laying down all 4" drill pipe. ',; 55. Change and test ram to,,5061Tpsi on 3 ''/2"and 2 3/8". Pick up 4" mill and 5" scraper and RIH picking up 2 3/8 Tubing. 0,)E e4^` f . Rte- .-m Y 1.S,, ) 8 • • 56. Clean out 5" liner to landing collar. Circulate hole clean. Test casing and liner lap to 4500 psi if past 24 hour CIP. Change over to completion fluid using appropriate spacers. 57. POH & stand back tubing. 58. Run CBL. Prepare squeeze program if necessary. 59. Completion Sundry to follow. Formation Integrity Test Procedure Surface and Intermediate casing shoes will be tested to Leak-off. Prior to drilling out of casing strings, test BOPs, and casing to the specified pressure listed in the BOP Program section. Plot test and record volume required on the drilling report. Leak-off tests (LOT)are to be conducted as described below: • Drill 20'to 25'of new formation below the casing shoe and condition the mud to the same properties in and out. • Pull drill bit into the casing shoe and close pipe ram preventer. Line up to the choke manifold with a closed choke. • Begin slowly pumping fluid down the drill string at 1/2 bpm while recording casing and drill pipe pressures at 1/2 bbl intervals. • A running plot of pressure versus volume should be kept by the Drill Site Manager while the test is in progress. • Stop pumping when the pressure curve departs form a straight line sufficiently to indicate leakage into the formation. Record as ppg equivalent mud density in the IADC and morning reports. • Monitor and plot pressure drop and time after shut-in for 10 minutes or until the shut-in pressure stabilizes. 9 • 0 Proposed Wellbore Diagram Olson Creek#2 Proposed Completion 1/1/14 i ti. i t 3/8" L80 200'ND 68# BTC 200'MD 12 1/4"Hole die 9 5/9" L-80 1,781'ND 40# BTC 2000'MD e !, • • TOL @ 7200'MD - �( 8.5"Hole I7" L80 6.961'TVD .129# BTC 8500'MD ir— Sliding Sleeve @ 9.500'MD • Hydraulic Set Packer @ 9.700' XN Nipple @ 9,750' U — y 2 3/8"L80 EUE Tubing L C01 ICS ator ice 1 i 6 1/8"Hole 5 L80 10.024'ND 16# BTC 11.967'MD 10 0 0 Time vs. Depth Plot WF-03 Time vs Depth Chart Rig Days on location 0 5 10 15 20 25 30 35 40 45 50 55 60 65 70 1I , { I j i. fi I ! 1000 1 [rill 61p('.• lids I 3000 1 J DE/Dimas, 1108,1.127 , --- I _ I 1 ! I 4000 — I 1 ' - I I I 5000 I 1 f - . 6000 ' I ( I k Drill Inion, in hole ( j I 1 I ILI 7000 1 1 ....% I 8000 ' _ -- 10000 - Dn0 8.5^Hole Steam �* 11000 --- -----Y-- 1 ---a,4 �,e - 12000 — --. �" 4' U' y+Y�.T_:'- ? I ___----- 13000 ` L I 14000 15000 16000 17000 — — — I ( I — — —_—� — 18000 -- - - - - + — ( 19000 iI w 1 i 11, t I1 ! ! ! 11 I • Directional Plan ._ Cook inlet Energy Cook Inlet Energy JI1I Location Cook Inlet,Alaska(Kenai Peninsula) Sot Olson 2 Slot MIMES Field Olson Creek Unt Well Olson2 Fadlar Olson Creek Wellbore' Olson2 WelPlan Plot reference wellpath is Olson 2 Ver1Y5 True vertical depths are referenced to Rig on Olson 2 Slot(RT) Grid System:NAD27/TM Alaska SP,Zone 4(5004),US feet Measured depths are referenced to Rig on Olson 2 Slot(RT) North Reference.Grid north Rig on Olson 2 Slot(RT)to Mean Sea Level:3244 feet Scale True distance Mean Sea Level to Mud line(At Slot Olson 2 Slot).0 feet Depths are in feet Coordinates are in feet referenced to Sot Created by:ulricard on 15/Jul2014 Well Profile Data Design Comment MD(I) tic(°) Az(°) TVD(fl) Local N(11) Local E(It) DLS(°/1008) VS(8) Tie On 0.00 0.000 283.720 0.00 0.00 0.00 0.00 0.00 End of Tangent 500.00 0.000 283.720 500.00 0.00 0.00 0.00 0.00 End of Build 1888.30 51.050 283.720 1711.77 137.24 -562.12 3.68 578.02 End of Tangent 2013.00 51.050 283.720 1790.16 160.24 -656.33 0.00 674.89 End of3DArc 2410.70 37.620 280.834 2074.00 220.01 -927.05 3.41 952.05 End of 3D Arc 2420.90 37.930 280.830 2082.06 221.19 -933.19 3.04 958.30 End of Tangent 7446.50 37.930 280.830 6046.07 801.64 -3967.39 0.00 , 4047.50 End of 3D Arc 7777.90 27.990 280.400 6323.78 834.90 -4144.37 3.00 4227.57 End of Tangent 11967.90 27.990 280400 10023.67 1189.88 -6078.50 0.00 6193.87 Easting(ft) -7000 -6000 -5000 -4000 -3000 -2000 -1000 0 10 ®1250 MO I 1 I I 1 I I "2000 k 17...1.4. 04.12 W"Fren 00144 1�, C qv 0. ' ‘re. .On TD_-3 - 1000 2 d to 375in Contactor . . a End of Tangent gone_P3 T2{g_P3 S uo 1250- 368'110011 V O� Olson 2 SIOt_ 0 9 629rAKA 9 629n Casng`b311'10011 9 GO�G� T21g_p 30//10011 End of 3D Arc 8 ,14'..,,,' 1 2500- �� --1000 3750 Z" C d 5000- qq P. E3300'1559 > 6250- TyonekP3 End of 3D Arc ? 7in Casngp b 7500 6750 10000- TD P3 r01 o!Tanpent 11250 O 1 551 1 ) 1 1 1 0423 1250 0 1250 Ve50al Sect3onl`ft) 5000 625 1'p 75,00 Azimuth 281 08'with reference 0.00 N,0 00 E 12 • MD N/S E/W DLeg (usft) Inc(°) Azi(°) TVD(usft) (usft) (usft) V.Sec.(usft) (°/100usft) Tool 1 2.7 0 0 2.7 0 0 0 0 UNDEFINED 2 100 0 360 100 0 0 0 0 MWD+SC+sag(1) 3 200 0 360 200 0 0 0 0 MWD+SC+sag(1) 4 300 0 360 300 0 0 0 0 MWD+SC+sag(1) 5 400 0 360 400 0 0 0 0 MWD+SC+sag(1) 6 500 0 360 500 0 0 0 0 MWD+SC+sag(1) 7 600 4 273.82 599.92 0.23 -3.48 3.47 4 MWD+SC+sag(1) 8 700 8 273.82 699.35 0.93 -13.91 13.87 4 MWD+SC+sag(1) 9 800 12 273.82 797.81 2.09 -31.23 31.14 4 MWD+SC+sag(1) 10 900 16 273.82 894.82 3.7 -55.36 55.2 4 MWD+SC+sag(1) 11 1000 20 273.82 989.91 5.76 -86.19 85.93 4 MWD+SC+sag(1) 12 1100 24 273.82 1082.61 8.26 -123.56 123.19 4 MWD+SC+sag(1) 13 1200 28 273.82 1172.47 11.18 -167.29 166.79 4 MWD+SC+sag(1) 14 1300 32 273.82 1259.05 14.52 -217.17 216.52 4 MWD+SC+sag(1) 15 1400 36 273.82 1341.94 18.25 -272.95 272.13 4 MWD+SC+sag(1) 16 1500 40 273.82 1420.73 22.35 -334.37 333.36 4 MWD+SC+sag(1) 17 1600 44 273.82 1495.02 26.81 -401.12 399.91 4 MWD+SC+sag(1) 18 1674.77 46.99 273.82 1547.43 30.37 -454.32 452.95 4 MWD+SC+sag(1) 19 1700 46.99 273.82 1564.64 31.6 -472.73 471.31 0 MWD+SC+sag(1) 20 1800 46.99 273.82 1632.85 36.48 -545.69 544.05 0 MWD+SC+sag(1) 21 1900 46.99 273.82 1701.06 41.35 -618.65 616.79 0 MWD+SC+sag(1) 22 2000 46.99 273.82 1769.27 46.23 -691.61 689.53 0 MWD+SC+sag(1) 23 2100 46.99 273.82 1837.49 51.11 -764.58 762.28 0 MWD+SC+sag(2) 24 2141.36 46.99 273.82 1865.7 53.13 -794.75 792.36 0 MWD+SC+sag(2) 25 2200 44.86 275.18 1906.49 56.42 -836.75 834.31 4 MWD+SC+sag(2) 26 2300 41.26 277.75 1979.54 64.06 -904.57 902.46 4 MWD+SC+sag(2) 27 2403.28 37.62 280.82 2059.3 74.58 -969.31 968.04 4 MWD+SC+sag(2) 28 2413.5 37.93 280.83 2067.38 75.76 -975.46 974.3 3 MWD+SC+sag(2) 29 2500 37.93 280.83 2135.61 85.75 -1027.68 1027.45 0 MWD+SC+sag(2) 30 2600 37.93 280.83 2214.49 97.3 -1088.05 1088.91 0 MWD+SC+sag(2) 31 2700 37.93 280.83 2293.37 108.86 -1148.41 1150.36 0 MWD+SC+sag(2) 32 2800 37.93 280.83 2372.25 120.41 -1208.78 . 1211.81 0 MWD+SC+sag(2) 33 2900 37.93 280.83 2451.13 131.96 -1269.15 1273.26 0 MWD+SC+sag(2) 34 3000 37.93 280.83 2530.01 143.51 -1329.52 1334.71 0 MWD+SC+sag(2) 35 3100 37.93 280.83 2608.89 155.06 -1389.89 1396.17 0 MWD+SC+sag(2) 36 3200 37.93 280.83 2687.77 166.62 -1450.26 1457.62 0 MWD+SC+sag(2) 37 3300 37.93 280.83 2766.65 178.17 -1510.63 1519.07 0 MWD+SC+sag(2) 38 3400 37.93 280.83 2845.53 189.72 -1571 1580.52 0 MWD+SC+sag(2) 39 3500 37.93 280.83 2924.41 201.27 -1631.37 1641.97 0 MWD+SC+sag(2) 13 • 0 40 3600 37.93 280.83 3003.29 212.82 -1691.74 1703.43 0 MWD+SC+sag(2) 41 3700 37.93 280.83 3082.18 224.38 -1752.1 1764.88 0 MWD+SC+sag(2) 42 3800 37.93 280.83 3161.06 235.93 -1812.47 1826.33 0 MWD+SC+sag(2) 43 3900 37.93 280.83 3239.94 247.48 -1872.84 1887.78 0 MWD+SC+sag(2) 44 4000 37.93 280.83 3318.82 259.03 -1933.21 1949.23 0 MWD+SC+sag(2) 45 4100 37.93 280.83 3397.7 270.58 -1993.58 2010.69 0 MWD+SC+sag(2) 46 4200 37.93 280.83 3476.58 282.14 -2053.95 2072.14 0 MWD+SC+sag(2) 47 4300 37.93 280.83 3555.46 293.69 -2114.32 2133.59 0 MWD+SC+sag(2) 48 4400 37.93 280.83 3634.34 305.24 -2174.69 2195.04 0 MWD+SC+sag(2) 49 4500 37.93 280.83 3713.22 316.79 -2235.06 2256.5 0 MWD+SC+sag(2) 50 4600 37.93 280.83 3792.1 328.35 -2295.43 2317.95 0 MWD+SC+sag(2) 51 4700 37.93 280.83 3870.98 339.9 -2355.79 2379.4 0 MWD+SC+sag(2) 52 4800 37.93 280.83 3949.86 351.45 -2416.16 2440.85 0 MWD+SC+sag(2) 53 4900 37.93 280.83 4028.74 363 -2476.53 2502.3 0 MWD+SC+sag(2) 54 5000 37.93 280.83 4107.62 374.55 -2536.9 2563.76 0 MWD+SC+sag(2) 55 5100 37.93 280.83 4186.5 386.11 -2597.27 2625.21 0 MWD+SC+sag(2) 56 5200 37.93 280.83 4265.38 397.66 -2657.64 2686.66 0 MWD+SC+sag(2) 57 5300 37.93 280.83 4344.26 409.21 -2718.01 2748.11 0 MWD+SC+sag(2) 58 5400 37.93 280.83 4423.14 420.76 -2778.38 2809.56 0 MWD+SC+sag(2) 59 5500 37.93 280.83 4502.02 432.31 -2838.75 2871.02 0 MWD+SC+sag(2) 60 5600 37.93 280.83 4580.9 443.87 -2899.12 2932.47 0 MWD+SC+sag(2) 61 5700 37.93 280.83 4659.78 455.42 -2959.48 2993.92 0 MWD+SC+sag(2) 62 5800 37.93 280.83 4738.67 466.97 -3019.85 3055.37 0 MWD+SC+sag(2) 63 5900 37.93 280.83 4817.55 478.52 -3080.22 3116.82 0 MWD+SC+sag(2) 64 6000 37.93 280.83 4896.43 490.07 -3140.59 3178.28 0 MWD+SC+sag(2) 65 6100 37.93 280.83 4975.31 501.63 -3200.96 3239.73 0 MWD+SC+sag(2) 66 6200 37.93 280.83 5054.19 513.18 -3261.33 3301.18 0 MWD+SC+sag(2) 67 6300 37.93 280.83 5133.07 524.73 -3321.7 3362.63 0 MWD+SC+sag(2) 68 6400 37.93 280.83 5211.95 536.28 -3382.07 3424.08 0 MWD+SC+sag(2) 69 6500 37.93 280.83 5290.83 547.84 -3442.44 3485.54 0 MWD+SC+sag(2) 70 6600 37.93 280.83 5369.71 559.39 -3502.81 3546.99 0 MWD+SC+sag(2) 71 6700 37.93 280.83 5448.59 570.94 -3563.17 3608.44 0 MWD+SC+sag(2) 72 6800 37.93 280.83 5527.47 582.49 -3623.54 3669.89 0 MWD+SC+sag(2) 73 6900 37.93 280.83 5606.35 594.04 -3683.91 3731.34 0 MWD+SC+sag(2) 74 7000 37.93 280.83 5685.23 605.6 -3744.28 3792.8 0 MWD+SC+sag(2) 75 7100 37.93 280.83 5764.11 617.15 -3804.65 3854.25 0 MWD+SC+sag(2) 76 7200 37.93 280.83 5842.99 628.7 -3865.02 3915.7 0 MWD+SC+sag(2) 77 7300 37.93 280.83 5921.87 640.25 -3925.39 3977.15 0 MWD+SC+sag(2) 78 7400 37.93 280.83 6000.75 651.8 -3985.76 4038.6 0 MWD+SC+sag(2) 79 7439.11 37.93 280.83 6031.61 656.32 -4009.37 4062.64 0 MWD+SC+sag(2) 80 7500 36.1 280.77 6080.22 663.19 -4045.37 4099.28 3 MWD+SC+sag(3) 14 • • 81 7600 33.1 280.65 6162.53 673.75 -4101.16 4156.05 3 MWD+SC+sag(3) 82 7700 30.1 280.51 6247.69 683.37 -4152.66 4208.44 3 MWD+SC+sag(3) 83 7770.48 27.99 280.4 6309.3 689.58 -4186.31 4242.65 3 MWD+SC+sag(3) 84 7800 27.99 280.4 6335.37 692.08 -4199.94 4256.51 0 MWD+SC+sag(3) 85 7900 27.99 280.4 6423.67 700.56 -4246.09 4303.43 0 MWD+SC+sag(3) 86 8000 27.99 280.4 6511.98 709.03 -4292.25 4350.36 0 MWD+SC+sag(3) 87 8100 27.99 280.4 6600.28 717.5 -4338.41 4397.28 0 MWD+SC+sag(3) 88 8200 27.99 280.4 6688.59 725.97 -4384.56 4444.2 0 MWD+SC+sag(3) 89 8300 27.99 280.4 6776.89 734.45 -4430.72 4491.13 0 MWD+SC+sag(3) 90 8400 27.99 280.4 6865.2 742.92 -4476.88 4538.05 0 MWD+SC+sag(3) 91 8500 27.99 280.4 6953.5 751.39 -4523.04 4584.98 0 MWD+SC+sag(3) 92 8600 27.99 280.4 7041.81 759.86 -4569.19 4631.9 0 MWD+SC+sag(3) 93 8700 27.99 280.4 7130.11 768.34 -4615.35 4678.83 0 MWD+SC+sag(3) 94 8800 27.99 280.4 7218.42 776.81 -4661.51 4725.75 0 MWD+SC+sag(3) 95 8900 27.99 280.4 7306.72 785.28 -4707.66 4772.68 0 MWD+SC+sag(3) 96 9000 27.99 280.4 7395.03 793.75 -4753.82 4819.6 0 MWD+SC+sag(3) 97 9100 27.99 280.4 7483.33 802.23 -4799.98 4866.53 0 MWD+SC+sag(3) 98 9200 27.99 280.4 7571.64 810.7 -4846.14 4913.45 0 MWD+SC+sag(3) 99 9300 27.99 280.4 7659.94 819.17 -4892.29 4960.38 0 MWD+SC+sag(3) 100 9400 27.99 280.4 7748.25 827.64 -4938.45 5007.3 0 MWD+SC+sag(3) 101 9500 27.99 280.4 7836.55 836.12 -4984.61 5054.22 0 MWD+SC+sag(3) 102 9600 27.99 280.4 7924.86 844.59 -5030.76 5101.15 0 MWD+SC+sag(3) 103 9700 27.99 280.4 8013.16 853.06 -5076.92 5148.07 0 MWD+SC+sag(3) 104 9800 27.99 280.4 8101.46 861.53 -5123.08 5195 0 MWD+SC+sag(3) 105 9900 27.99 280.4 8189.77 870.01 -5169.24 5241.92 0 MWD+SC+sag(3) 106 10000 27.99 280.4 8278.07 878.48 -5215.39 5288.85 0 MWD+SC+sag(3) 107 10100 27.99 280.4 8366.38 886.95 -5261.55 5335.77 0 MWD+SC+sag(3) 108 10200 27.99 280.4 8454.68 895.42 -5307.71 5382.7 0 MWD+SC+sag(3) 109 10300 27.99 280.4 8542.99 903.9 -5353.86 5429.62 0 MWD+SC+sag(3) 110 10400 27.99 280.4 8631.29 912.37 -5400.02 5476.55 0 MWD+SC+sag(3) 111 10500 27.99 280.4 8719.6 920.84 -5446.18 5523.47 0 MWD+SC+sag(3) 112 10600 27.99 280.4 8807.9 929.31 -5492.34 5570.4 0 MWD+SC+sag(3) 113 10700 27.99 280.4 8896.21 937.79 -5538.49 5617.32 0 MWD+SC+sag(3) 114 10800 27.99 280.4 8984.51 946.26 -5584.65 5664.25 0 MWD+SC+sag(3) 115 10900 27.99 280.4 9072.82 954.73 -5630.81 5711.17 0 MWD+SC+sag(3) 116 11000 27.99 280.4 9161.12 963.2 -5676.96 5758.09 0 MWD+SC+sag(3) 117 11100 27.99 280.4 9249.43 971.68 -5723.12 5805.02 0 MWD+SC+sag(3) 118 11200 27.99 280.4 9337.73 980.15 -5769.28 5851.94 0 MWD+SC+sag(3) 119 11300 27.99 280.4 9426.04 988.62 -5815.44 5898.87 0 MWD+SC+sag(3) 120 11400 27.99 280.4 9514.34 997.09 -5861.59 5945.79 0 MWD+SC+sag(3) 121 11500 27.99 280.4 9602.65 1005.57 -5907.75 5992.72 0 MWD+SC+sag(3) 15 • • 122 11600 27.99 280.4 9690.95 1014.04 -5953.91 6039.64 0 MWD+SC+sag(3) 123 11700 27.99 280.4 9779.26 1022.51 -6000.06 6086.57 0 MWD+SC+sag(3) 124 11800 27.99 280.4 9867.56 1030.98 -6046.22 6133.49 0 MWD+SC+sag(3) 125 11900 27.99 280.4 9955.87 1039.46 -6092.38 6180.42 0 MWD+SC+sag(3) 11960.5 126 1 27.99 280.4 10009.3 1044.58 -6120.31 6208.81 0 . MWD+SC+sag(3) 16 • • cell Clearance Report IrdiiIIII Cook Inlet EnergyOlson 2 rBAKER Closest Approach Page 1 of 25 HUGHES Operator Cook Inlet Energy .Slot Olson 2 Slat Area Cook Inlet,Alaska(Katal Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek 1111111111111.1111 Rr �. Projection System NAD27 I TM Alaska SP,Zone 4(5004), Software System WellArchltect®4.0.1 US feet North Reference Grid User Ulricard Scale 0.999946 Report Generated 03/Jun/2014 at 15:10 1 Convergence at slot 1.00°West IDatabase/Source file WA Andiorage Server/Olson 2 Wellfan_CR.xml' \\ELLPAIII LOCATION Local coordinates Grid coordinates Geographic coordinates __ North[ft] 1 East[it] Easting[US ft] Northing[US ft] Latitude Longitude Slot Location 0.00 0.00 299832.00 2648980.00 61°14'44.259"N 151°08'11.361"W Facility Reference Pt I i 299832.00 2648980.00 61°14'44.259"N 151°08'11.361"W Field Reference Pt ( I r 299862.99 ; 2648974.54 i 61°14'44.211"N 151°08'10.726"W \\I;I I.I'\11l I)VII \I Calculation method 'Minimum Curvature D Oon lson 2 Slot(RT)to Facility Vertical 324.40n um Horizontal Reference Pt Slot Rig on Olson 2 Slot(RT)to Mean Sea Level 324.40ft Vertical Reference Pt Rig on Olson 2 Slot(RT) Rig on Olson 2 Slot(RT)to Mud Line at Slot 324.40ft (Olson 2 Slot) MD Reference Pt Rig on Olson 2 Slot(RT) Field Vertical Reference Mean Sea Level POSITIONAL UNCERTAINTY CALCULATION SETTINGS Ellipse Confidence Limit 3.00 Std Dev Ellipse Start MD 324.40ft Surface Position Uncertainty induded Declination 17.04°East of TN Dip Angle 74.08° Mag Field Strength 55651 nT ' Slot Surface Uncertainty(41SD Horizontal 2.000ft Vertical 1.00011 _ Facility Surface Uncertainty(1SD Horizontal 20.000ft Vertical 3.000f1 Positional Uncertainty values in the WELLPATH DATA table are the projection of the ellipsoid of uncertainty onto the vertical and horizontal planes €6 17 11111 III tae Clearance Report /ARV Olson 2r BAKER _ Cook Inlet Energy__ Closest Approach Page 2 of 25 I4 ES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WeliPlan Facility Olson Creek I ANTI-COLLISION RULE Rule Name E-type Closest Approach w/Hole&Csg Limit:O,StdDev:3.00 Rule Based On Ellipsoid Separation iw/Surface Uncert Plane of Rule !Closest Approach Threshold Value 0.00R ISubtract Casing&Hole Size yes Apply Cone of Safety no HOLE&CASING SECTIONS-Ref Wellbore:Olson 2 WetlPlan Rerwelipath:Olson 2 Ver#4 String/Dlameter Start MD End MD Interval Start TVD End TVD Start NIS Start VW End N/S End EJW [ft] [n] [U] [ft] [n] lit] [ftl [rt] [ft] 13375in Conductor 0.00 200.00 200.001 0.00 200.00 0.00 0.00 0.001 0.00 9.625in Casing 0.00 2000.00 2000.00 0.00 178199 0.00 0.00 157.841 -646.51 lin Casing 0.00 7500.00 7500.00' 0.00 6088.72 0.00 0.00 807.69.3999.1.1, 5inLiner 7200.00 11968.00 4768.00 5851.64 NA 773.17 -381857 NA1- NA SURVEY PROGRAM- Ref wellbore:Olson 2 WellPlan Ref Wellpath:Olson 2 Ver#4 Start MD End MID Positional Uncertainty ModelfLog Na ne/Coanment Wellbore [ft] [ft] 324.40 11967.90NaviTrak(MagCorr) Olson 2 WellPlan CALCULATION RANGE&CUTOFF From:0.00f1 MD To:11967.90ft MD C-C Cutoff(none) OFFSET WELL CLEARANCE SUMMARY(4 Offset Wdlpaths sleeted)Ellipse separations calculated in Closest Approach plane I C-C Clearance Distance ACR Ellipse Separation Distance Ref Mm C-C Diverging Ref MD of Min Min Ell Sep ACR Offset Offset Offset Offset Offset MD Clear Dist from MD Min Ell Sep Ea Sep Dvrg from Status Facility Slot Well WelI,ore Wellpath [R] [R] [ft] [R] [ft] Al Olson Creek Olson 1 Slot Olson 1 Olson 1 Olson 1 205 00, 31.15 205.00 417.90 20.41 417.90 PASS Olson Creek Olson 1 Slot Olson 1 PBt Olson I PRI Olson 1 PB1 205.00 31.15 205.00 417.90 20.41 417.90 PASS Otter Otter#1 Otter#1 Otter#1A NaviTrak MWD<4436-7021'> 160.00 38436.41 160.00 684.43 38321.98 684.43 PASS Otter Otter#1 Otter#1 Otter#1 Otter#1<0-5686> 1160.00 38436.41 160 00 684.43 38322.09 684.43 PASS ea 18 • • ira Clearance Report FARM Cook Inlet Ener Olson 2 rBAKER - Energy Closest Approach Page 3 of 25 HES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek I CLEARANCE DATA-Offset Wellbore:Olson 1 Offset Wellpath:Olson 1 Facility:Okm Creek Slot:Olsm 1 Slot Welt Olsm 1 Threshold Value=.00 ft 4.=Interpolated/extrapolated statim Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Horn C-C ACR Ellipse ACR [n] py Ft) PI irti [IL] [ICI [R] Bearing Clear Dist MASD Sep Status [y [It] [fy [a] 0.00 0.00 0.00 0.00` 15.30 32.801 -5.49 30.99 100.05 45.46 1.01 44.45 PASS 100.00} 100.00 0.00 0.00 8258 10008 -5.04 3098 99.24 31.39 1.01 30.38 PASS 200.00} 200.00 0.00 o.00r 18256 200.02 -2.48 31.05 94.56 31.15 0.88 30.28 PASS 205.00} 205.00 0.00 0.007 18750 204.96 -2.28 31.07 94.20 31.15 0.72 30.43 PASS 300.00} 300.00 0.00 0.00 282.43 299.78 2.17 3138 86.05 31.45 0.72 30.73 PAS, 400.00} 400.00 0.00 0.00 382.16 399.35 7.83 31.80 76.16 32.76 11.65 21.11 PASS I 417.90} 417.90 0.00 0.00 400.00 417.15 8.95 31.90 74.33 33.14 12.72 20.41 PASS 500.00 500.00 0.00 0.00 481.79 498.76 14.50 3236 65.87 35.48 12.75 22.74 PASS 600.00} 599.93 0.76 -3.12 58129 597.95 22.22 32.93 59.24 42.00 12.93 29.07 PASS 700.00} 699.45 3.04 -12.45 68039 696.67 30.89 33.44 58.75 53.75 13.44 40.31 PASS 800.00} 798.15 6.83 -27.97 778.67 794.46 40.66 33.69 61.25 70.43 14.12 56.31 PASS 900.00f 895.62 12.11 -49.60 875.84, 891.00 51.74 33.61 64.53 92.28 14.72 77.56 PASS 1000.00} 991.46 18.86 -77.27 97150' 985.87 64.01 3323 67.78 119.49 15.49 104.01 PASS 1100.00f 1085.28 27.06 -110.85 106538 1078.80 77.27 32.67 70.72 152.19 16.28 135.90 PASS 1200.00} 1176.69 36.67 -150.20 115735 1169.66 91.49 31.88 73.24 190.28 17.12 173.16 PASS 1300.004- 1265.31 47.65 -195.17 1246.27 1257.27 106.66 30.80 75.36 233.68 17.97 215.70 PASS 1400.00} 1350.78 59.95 -245.56 1332.04 1341.54 122.63 29.88 77.18282.64 18.86 263.78 PASS 1500.00} 1432.75 73.53 -301.18 141531 1423.27 139.50 28.80 78.701 336.64 19.78 316.86 PASS 1600.00} 1510.88 88.33 -361.79 1494.07 1499.85 157.00 27.70 80.00 395.65 20.72 374.94 PASS 1700.00} 1584.84 104.29 -427.15 1569.40 1572.86 175.54 26.62 81.08 459.48 21.71 437.78 PASS 1800.00} 1654.34, _ 121.33 -496.97 1638.63 1639.51 194.20 25.62 82.06 527.86 22.66 505.20 PASS 1888.30 1 1711.777 137.24 -562.12 1694.42 1692.88 210.45 2.5.09 82.89 592.06 23.52 568.54 PASS 1900.00} 1719.12 139.40 -570.96 1702.021 1700.13 212.74 _ 25.04, 82.98 600.80 23.6.5 577.15 PASS 2000.00} 1781.99 157.84 646.51 1763227 1759.14 228.89 24.85' 83.96 675.49 24.49 651.01 PASS 2013.00 1790.16 160.24 -656.33 176930 1765.24 230.42 24.90 84.12 685.29 24.46 660.83 PASS 2100.00} 1846.57 175.66 -720.74 1826.40 1820.51 243.92 2.5.43 84.77 749.73 25.22 724.52 PASS 2200.00} 1915.50 191.80 -791.34 189858 1890.85 260.07 26.29 85.23 820.85 26.15 794.70 PASS 2300.00} 1988.58 206.19 -858.05 1972.73 1963.45 275.14 27.18 85.55 888.27 27.08 861.19 PASS 2400.00} 2065.55 218.77 -920.61 2059.65 2048.89 291.08 27.83 85.6.4 951.34 28.11 923.23 PASS 2410.70 2074.00 220.01 -927.05 2068.44 2057.56 292.56 27.87 85.66 957.81 28.19 929.62 PASS €1 19 • i er13 Clearance Report FARO Cook Inlet EnergyOlson 2 rER Closest Approach Page 4 of 25 HES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek CLEARANCE DATA-Offset Wellbore:Olson 1 Offset Wellpnth:Olson 1 Facility:Olson Creek Slot:Olson 1 Slot Well Olson 1 Threshold Value=0.00 ft t=Interpolated/extrapolated statim Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Horiz C-C ACR Ellipse ACR [nl [ft] p't] (<t] la] Ft] VII pt] Bearing Clear Dist MASD Sep Status P] Ift] [R] Rtl 2420.90 2082.06 221.19 -933.19 2076.14 2065.15 293.84 27.90 85.68 963.98 28.27 935.71 PASS_ 2500.00} 2144.45 230.32 -980.95 2136.32 2124.57 303.36 28.34 85.86 1012.12 28.86 983.25 PASS 2600.00} 2223.33 241.87 -104132 2212.71 2200.13 314.49 29.07 86.12 1073.10 29.61 1043.49 PASS 2700.00} 2302.21 2.53.42 -1101.70 2292.99 2279.87 323.75 30.15 86.44 1134.25 30.34 1103.91 PASS 2800.00} 2381.08 264.97 -1162.07 2377.17 2363.74 330.85 31.10 86.84 1195.11 31.04 1164.07 PASS 2900.00} 2459.96 276.52 -1222.45 2456.07 2442.48 335.67 32.01 87.30 1255.97 31.63 1224.35 PASS 3000.00tj 2338.83 288.07 -1282.82 2541.14 2527.51 338.46 32.86 87.81 1316.69 32.19 1284.50 PASS 3100.00}' 2617.71 299.62 -1343.20 2615.46 2601.82 338.71 33.52 88.37 137736 32.61 1344.75 PASS 3200.00} 2696.59 311.17 -1403.57 2688.72 2675.06 337.46 34.49 88.95 1438.47 32.98 1405.49 PASS 3300.001 2775. - "+ -1463.95 276527 2751.57 33536 35.72 89.52 1499.91 33.35 1466.56 PASS 3400.00} 2854.34 334.27 -1524.32 2847.69 2833.96 333.25 36.92 90.04 156137 33.77 1527.60 PASS 3500.00} 2933.22 345.82 -1584.70 2925.22 2911.46 331.40 37.99 90.51 1622.89 34.18 1588.71;PASS 3600.001 3012.09 357.37 -1645.07 3011.72 2997.93 329.50 38.89 90.95 1684.25 34.67 1649.57[1-.A-SS 3700.001 3090.97 368.92 -1705.45 3092.02 3078.21 327.97 39.48 91.34 1745.46 35.15 1710.31 PASS 3800.001 3169.84 380.47 -1765.82 3167.01 3153.19 326.75 40.07 91.70 1806.77 35.61 1771.16.PASS 3900.001 3248.72 392.02 -1826.20 3248.72 3234.89 325.60 40.74 92.04 1868.17 36.13 11332.041 PASS 4000.001 3327.60 403.57 -1886.57 3330.99 3317.15 324.6541.22 92.34 1929A4 36.68 1892.76 PASS 4100.001 3406.47 415.12 -1946951_ 3411.00 3397.16 323.78 41.58 92.63 1990.64 37.23 1953.42 PASS 4200.00} 3485.35 426.67 -2007.32 3489.98 3476.13 323.04 41.90 92.90 2051.86 37.78 2014.08 PASS 4300.001 3564.23 438.22 -2067.70 3568.59 3554.74 322.44 42.22 93.14 2113.11 38.35 2074.77 PASS 4400.001 3643.10 449.77. -2128.07 3647.54 3633.68 322.01 42.56 93.37 2174.41 38.93 2135.48 PASS 4500.00} 3721.98 461.321 -2188.45 3730.92 3717.07 321.69 42.82 93.58 2235.64 39.56 2196.07 PASS 4600.001 3800.85 472.871 -2248.82 3817.44 3803.58 321.58 42.85 93.78 2296.66 40.24 2256.42 PASS 4700.001 3879.73 484.42' -2309.20 3900.15 3886.29 321.58 42.69 93.96 235752 40.89 2316.63 PASS 4800.001 3958.61 495.97 -2369.57 3980.08 3966.23 321.72 42.46 94.13 241833 41.54 2376.79 PASS 4900.001 4037.48 507.52 -2429.95 4069.11 4055.25 322.14 42.05 94.29 2479.00 42.27 2436.72 PASS 5000.001 4116.36 519.07 -2490.32 4161.57 4147.71 322.74 41.19 94.44 253931 43.05 2496.26 PASS 5100.001 4195.24 530.62 -2550.70 4242.46 4228.59 323.41 40.20 94.57 259939 43.74 2555.65 PASS 5200.001 4274.11 542.17 -2611.07 4322.91 4309.03 324.18 39.22 94.70 2659.47 44.43 2615.04 PASS 5300.001 4352.99 553.72 -2671.45 4397.92 4384.03 324.68 38.31 94.83 2719.60 45.07 2674.52 PASS €5 20 i i cell Clearance Report FARO! Olson 2r BAKER Cook Inlet Energy Closest Approach Page 5 of 25 HES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot ,Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek i ______________] CLEARANCE DATA-Offset Wellbore:Olson 1 Offset Wellpsth:Olson 1 Facility:Olson Creek Slot:Olson 1 Slot Welk Olson 1 Threshold Value-0.00 ft t=interpolated/extrapolated station Ref MD Ref TVD Ref North Ref East Offset MID Offset TVD Offset North Offset East Horn C-C ACR Ellipse ACR [R] [ft] [ft] [ft] [R] [ft] [ft] fit] Bearing Clear Dist MASD Sep Status P1 [R1 [a] Ertl 5400.00} 4431.86 565.27 -2731.82 4465.60 ...4451.71 324.55 37.64 94.97 2779.97 45.65 2734.32 PASS 5500.00} 4510.74 576.82 -2792.20 4526.87 4512.98 323.96. 37.34 95.11 2840.81 46.16 2794.65 PASS 5600.00} 4589.62 588.37 -2852.57 4603.53 4589.62 _ 322.89 37.22 95.25 2901.96 46.80 2855.17 PASS 5700.00} 4668.49 599.92 -2912.95 4685.99 4672.08 321.70 37.08 95.39 2963.11 47.49 2915.63 PASS 5800.00} 4747.37 611.47 -2973.32 4768.02 4754.10 320.58 36.82 95.52 3024.17 48.19 2975.98 PASS 5900.00} 4826.25 623.02 -3033.70 4851.96 4838.03 319.55 36.48 95.65 3085.16 48.91 3036.25 PASS 6000.00} 4905.12 634.57 -3094.07 4932.01 4918.07 318.48 36.02 95.77 3146.04 49.61 3096.43 PASS 6100.00} 4984.00 646.12 -3154.45 5010.04 4996.10 317.42 35.62 95.88 3206.98 50.29 3156.69 PASS 6200.00} 5062.87 657.67 -3214.82 5095.40 5081.44 316.40 35.13 95.99 3267.88 51.04 3216.84 PASS 6300.00} 5141.75 669.22 -3275.20 5160.00 5146.04 315.64 154.59 96.10 3328.62 51.63 3277.00 PASS 6400.00} 5220.63 680.77 -3335.57 5160.00 5146.04 315.64 34.59 96.18 3390.71 51.67 3339.04 PASS 6500.00} 5299.50 692.32 -3395.95 5160.00 5146.04 315.64 34.59 96.27 3454.57 51.69 3402.87 PASS 6600.00} 5378.38 703.87 -3456.32 5160.00 5146.04 315.64 34.59 96.35 3520.111 51.71 3468.40 PASS 6700.00} 5457.25 715.42 -3516.70 5160.00 5146.04 315.64 34.59 96.42 3587.24 51.71 3535.53 PASS 6800.001- 5536.13 726.97 -3577.07 5160.00 5146.04 315.64 34.59 96.50 3655.88 51.71 3604.17 PASS 6900.00} 5615.01 738.52 -3637.44 5160.00 5146.04 315.64 34.59 96.57 3725.94 51.70 3674.24 PASS 7000.00} 5693.88 750.07 -3697.82 5160.00 5146.04 315.64 34.59 96.64 3797.34 51.68 3745.65 PASS 7100.00} 5772.76 761.62 -3758.19 5160.00 5146.04 315.64 34.59 96.71 3870.00 51.67 3818.33]PASS 7200.00} 5851.64 773.17 -3818.57 5160.00 5146.04 315.64 34.59 96.77 3943.86 51.65 3892.22 PASS 7300.00} 5930.51 784.72 -3878.94 5160.00 5146.04 315.64 34.59 96.84 4018.86 51.63 3967.23 PASS 7400.00} 6009.39 796.27 -3939.32 5160.00 5146.04 315.64 34.59 96.90 4094.92 51.61 4043.31 PASS 7446.50 6046.07 801.64 -3967.39 5160.00 5146.04 315.64 34.59 96.92 4130.63 51.60 4079.04 PASS 7500.00}I 6088.72 807.69 -3999.11 5160.00 5146.04 315.64 34.59 96.96 417152 51.58 4119.93 PASS 7600.00}1 6170.80 818.31 -4055.22 5160.00 5146.04 315.64 34.59 97.01 4246.10 51.46 4194.64 PASS 7700.00} 6255.76 828.01 -4107.05 5160.00 5146.04 315.64 34.59 97.05 4318.24 51.41 4266.83 PASS 7777.90 6323.78 834.90 -4144.37 5160.00 5146.04 315.64 34.59 97.08 4372.69 51.34 4321.34 PASS 7800.00} 6343.29 836.77 -4154.57 5160.00 5146.04 315.64 34.59 97.09 4387.95 51.32 4336.63 PASS 7900.00} 6431.60 845.24 -4200.73 5160.00 5146.04 315.64 34.59 97.13 4457.70 51.19 4406.51 PASS 8000.00} 6519.90 853.72 -4246.89 5160.00 5146.04 315.64 34.59 97.16 4528.59 51.08 4477.51 PASS 8100.001- 6608.20 862.19 -4293.05 5160.00 5146.04 315.64 34.59 97.20 4600.56 50.97 4549.59 PASS €8 21 • • cell Clearance Report IF/11111 Cook Inlet EnerOlson 2 rBAKER -- --_-.-_EnergyClosest Approach Page 6 of 25 HUGHES REFERENCE WELLPATH IDENTIFICATIO\ Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WeilPlan Facility Olson Creek CLEARANCE DATA-Offset Wellbore:Olson 1 Offset Wellpath:Olson 1 Facility:Olson Creek Slot:Olson 1 Slot Welt Olson 1 Threshold Value=0.00 ft }=interpolated/extrapolated station Ref MI) Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Horn C-C ACR Ellipse ACR [ft] [ft] [R] [R] [ft] [ft] [ft] [R] Bearing Clear Dist MASD Sep Status 1°] [ft] [ft] 8t] 8200.001 6696.51 870.66 -4339.21 5160.00 5146.04 315.64 34.59 97.23 467356 50.87 4622.69.PASS 8300.00} 6784.81 879.13 -438.537 5160.00 5146.04 315.64 34.59 9727 474754 50.78 4696.77;PASS 8400.001 6873.11 887.60 -443133 5160.00 5146.04 315.6434.59 9730 4822.47(' 50.69 4771.781 PASS 8500.00t 6961.41 896.08 -4477.69 5160.00 5146.04 315.64 34.59 97.33 4898291 50.62 4847.67.PASS 8600.00} 7049.72 904.55 4523.86 5160.00 5146.04 315.64 34.59 9736 4974.96 50.5.5 4924.41 PASS 8700.001 7138.02 913.02 -4570.02 5160.00 5146.04 315.64 34.59 9739 5052.45 50.50 5001.96 PASS 8800.00} 7226.32 921.49 -4616.18 5160.00 5146.04 315.64 34.59 97.42 5130.72 50.45 5080.27 PASS 8900.00} 7314.63 929.96 -4662.34 5160.00 5146.04 315.64 34.59 97.45 5209.73 50.41 5159.32 PASS 9000.00} 7402.93 938.44 -470850 5160.00 5146.04 315.64 34.59 97.48 5289.45 5039 5239.07 PASS 9100.00} 7491.23 946.91 -4754.66 i -60.00 5146.04 315.64 34.59 9731 5369.86 5037 5319.48 PASS 9200.001 7579.54 955.38 -4800.82 5160.00 5146.04 315.64 34.59 9754 5450.91 5037 5400.54 PASS 9300.001 7667.84 963.85 -4846.98 5160.00 5146.04 315.64 34.59 9756 553258 5038 5482.20 PASS 9400.001 7756.14 972.32 -4893.14 5160.00 - 5146.04 315.64 34.59 9739 5614.84 5039 5564.45 PASS 9500.001 7844.44 980.80 -493930 5160.00 5146.04 315.64 34.59 97.62 5697.67 50.42 5647.25 PASS 9600.001 7932.75 989.27 -4985.46 5160.00411g:5146.04 315.64 34.59 97.64 5781.04 50 A6 5730.58 MA 9700.00} 8021.05 997.74 -5031.62 5160.00 5146.04 315.64 34.59 97.67 5864.94 5051 5814.42,PASS 9800.001 8109.35 1006.21 -5077.78 5160.00. 5146.04 315.64 34.59 97.69 594933 5057 5898.751 PASS 9900.00} 8197.66 1014.68 -5123.95 5160.00. 5146.04 315.64 34.59 97.72 6034.20 50.65 5983.551 PASS 10000.00} 8285.96 1023.16 -5170.11 5160.00 5146.04 315.64 34.59 97.74 611932 50.73 6068.79 PASS 10100.00} 8374.26 1031.63 -521627 5160.00 5146.04 315.64 34.59 97.77 6205.29 50.82 6154.46 P 10200.00} 8462.56 1040.10 -5262.43 5160.00 5146.04 315.64 34.59 97.79 6291.47k 50.93 6240.54 PASS 10300.00} 8550.87 1048.57 -530839 5160.00 5146.04 315.64 34.59 97.81 6378.06 51.04 6327.01 PASS 10400.00} 8639.17 1057.05 -5354.75 5160.00 5146.04 315.64 34.59 97.83 6465.03 51.17 6413.86 PASS_ 10500.00} 8727.47 1065.52 -5400.91 5160.00 5146.04 315.64 34.59 97.86 6552.38 5131 6501.07 PASS 10600.00} 8815.78 1073.99 -5447.07 5160.00 5146.04 315.64 34.59 97.88 6640.08 51.45 6588.63 PASS 10700.00} 8904.08 1082.46 -549323 5160.00 5146.04 315.64 34.59 97.90 6728.13 51.61 6676.51 PASS 10800.001 8992.38 1090.93 -553939 5160.00 5146.04 315.64 34.59 97.92 681630 51.78 6764.72 PASS 10900.001 9080.69 1099.41 -558535 5160.00 5146.04 315.64 34.59 97.94 690520 51.96 6853.24 PASS 11000.001 9168.99 1107.88 -5631.71 5160.00 5146.04 315.64 34.59 97.96 6994.19 52.15 6942.05 PASS 11100.001 9257.29 111635 -5677.87 5160.00 5146.04 315.64 34.59 97.98 7083.49 5235 7031.14 PASS €8 22 • • cels Clearance Report Ird'ill Cook Inlet EnergyOlson 2 rBAKER -- - Closest Approach Page 7 of 25 HUGHES REFERENCE WELLPATH DENTIFICATIO Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek CLEARANCE DATA-Offset Wellbore:Olson 1 Offset Wellpath:Olson 1 1 Facility:Olsm Creek Slot:Olson 1 Slot Welt Olson 1 Threshold Value-0.00 ft }=interpolated/extrapolated station Ref MD Ref TVD Ret North Ref East Offset MD Offset TVD Offset North Onset East Bork C-C ACR Ellipse ACR [ft] Ft] [ft] [ft] pt] [ft] pt] Ft] Bearing Clear Dist MASD Sep Status P] [O [ft] Ift] 11200.00} 9345.59 1124.82 -5724.03 5160.00' 5146.04 315.64 34.59 98.00 7173.06 52.55 7120.51 PASS 11300.00+ 9433.90 1133.29 -5770.20 5160.00 5146.04 315.64 34.59 98.02 7262.91 52.77 7210.14 PASS 11400.00+ 9522.20 1141.77 -5816.36 5160.00 5146.04 315.64 34.59 98.04 7353.02 53.00 7300.02 PASS 11500.00+ 9610.50 1150.24 -5862.52 5160.00 5146.04 315.64 34.59 98.06 7443.38 53.24 7390.14 PASS 11600.00+ 9698.81 1158.71 -5908.68 5160.00 5146.04 315.64 34.59 98.07 7533.98 53A1 7480.50 PASS 11700.00+ 9787.11 1167.18 -5954.84 5160.00 5146.04 315.64 34.59 98.09 7624.82 53.74 7571.08 PASS 11800.00+ 9875.41 1175.65 -6001.00 5160.00 5146.04 315.64 34.59 98.11 7715.89 54.00 7661.89 PASS 11900.00+ 9963.72 1184.13 -6047.16 5160.00 5146.04 315.64 34.59 98.13 7807.17 54.28 7752.90 PASS 11967.90 10023.67 1189.88 -6078.50 5160.00 5146.04 315.64 34.59 98.14 7869.28 54.47 7814.81 PASS POSITIONAL UNCERTAINTY- Offset Wellbore:Olson 1 Offset Wellpath:Olson 1 ..j Slot Surface Uncertainty( 1SD Horizontal 2.00011 Vertical 1.000ft Facility Surface Uncertainty @1 SD Horizontal 20.000ft Vertical 3.00011 HOLE&CASING SECTIONS-Offset Wellbore•.Olson 1 Offset Wellpath:Olson 1 String/Diameter Start MD End MD Interval Start TVD End TVD i StartN/S Stale E/W End N/S End VW Kg [ft] [n] [n] [n] [n] [n] [n] MI 10.75in Conductor 15.30 157.00 141.701 48.10 189.78 3.35 18.89 -2.70 18.90 7.6251n Casing 15.30 1600.00; 1584.70 48.10 1617.67-3.35 18.89 54.28 17.42 6.75in Open Hole 15.30 1600.00[ 1584.70 48.10 1617.67[ -3.35 18.89 54.28 17.42 ' 6.75in Open Hole 1600.00 5643.00 4043.00 1617.67 NA 54.28 17.42 NA NA ea 23 • 0 ceB Clearance Report IF/fill Olson 2 2Ver#4BAKER Cook Inlet Energy Closest Approach Page 8 of 25 HES REFERENCE WELLPATH IDENTIFICATION mearzetasa Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WeliPian Facility Olson Creek WELLPATH COMPOSITION-Offset Wellbore:Olson 1 Offset Welipath:Olson 1 I Start MD End MD Positional Uncertainty Model Log Nemdnm Corent Wellbore 1 [ft] [rt] _ 15.30 1600.00 Generic gyro-continuous(Standard) Olson 1 PB1 Gyro<0-1850> Olson 1 PB1 — 1600.00 5160.00 ISCWSA MWD,Rev.2,axial magnetic correction(Standard) Olson 1 Olson 1 OFFSET WELLPATH MD REFERENCE- Offset Wetmore:Olson I Offset Wellpath:Olson 1 MD Reference:Rig on Olson 1(RKB) Offset TVD&local coordinates use Reference ilellpath settings (See WELLPATH DATUMon page I of this report) Ellipse Start MD 339.70ft €1 24 • ! cell Clearance Report .dii. Cook Inlet EnergyOlson 2 a4 BAKER _ C blest Approach Page 9 of 25 HUGHES -,:yyj ATH IDENTIFICATION Operator Cook Inlet Energy Slot Olson 2 Slot ___________]... Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 .Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek CLEARANCE DATA-Offset Wellbore:Olson 1 PBI Offset Wellpnth:Olson 1 PB1 Faculty:Olson Creek Slot:Okon 1 Slot Welk Olson 1 PB1 Threshold Value=0.00 ft }=Interpolated/extrapolated station Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Onset North Offset East Horh C-C ACR Ellipse ACR [81 [ft] Pt] [rt] al 181 [ft] [ft] Bearing Clear Dist MASD Sep Status P] [ft] [ft] RI 0.00 0.00 0.00 0.00 1530 32.80 -5.49 3099 100.05 45.46 1.01 44.45 PASS_ 100.00 100.00 0.00 0.00 82.58 100.08 -5.04 30.98 99.24 31.39 1.01 30.38 PASS 200.001. 200.00 0.00 0.00 182.56 200.02 -2.48 31.05' 94.56 31.15 0.88 30.28,PASS 205.00.} 205.00 0.00 0.00 187.50 204.96 -2.28 31.07. 94.20 31.15 0.72 30.43 PASS 300.001. 300.00 0.00 0.00 282.43 299.78 2.17 3138 86.05 31.45 0.72 30.73 PASS 400.00t 400.00 0.00 0.00 382.16 399.35 7.83 31.80 76.16 32.76 11.65 21.11 PASS 417.90t 417.90 0.00 0.00 400.00 417.15 8.95 31.90 74.33 33.14 12.72 20.41 PASS 500.00 500.00 0.00 0.00 481.79 498.76 14.50 3236 65.87 35.48 12.75 22.74 PASS 600.001 599.93 0.76 -3.12 581.29 597.95 22.22 32.93 59.24 42.00 12.93 29.07 PASS 700.001. 699.45 3.04 -12.45 68039 696.67 30.89 33.44 58.75 53.75 13.44 40.31 PASS 800.00/. 798.15 6.83 -27.97 778.67 794.46 40.66 33.69 61.25 70.43 14.12 56.31 PASS 900.00/. 895.62 12.11 -49.60 875.84 891.00 51.74 33.61 64.53 92.28 14.72 77.56 PASS 1000.00/. 991.46 18.86- -77.27 97150 985.87 64.01 33.23 67.78 119.49 15.49 104.01 PASS 1100.001. 1085.28 27.06 -110.85 106538 1078.80 77.27 32.67 70.72 152.19 16.28 135.90 PASS 1200.001 1176.69 36.67 -150.20 1157.35 1169.66 91.49 31.88 73.24 190.28 17.12 173.16 PASS 1300.00/. 1265.31 47.65 -195.17 1246.27 1257.27 106.66 30.80 75.36 233.68 17.97 215.70 PASS 1400.00/. 1350.78 59.95 -245.56 1332.04 1341.54 122.63 29.88 77.18 282.64 18.86 263.78 PASS 1500.00/. 1432.75 73.53 -301.18 141551 1423.27 139.50 28.80 78.70 336.64 19.78 316.86 PASS 1600.00.} 1510.88 88.33 -361.79 1494.07 1499.85 157.00 27.70 80.00 395.65 20.72 374.94 PASS 1700.001 1584.84 104.29 -427.15 1569.40 1572.86 175.54 26.62 81.08 459.48 21.71 437.78 PASS 1800.00t 1654.34 121.33 -496.97 1639.66 _1640.50 194.49 2556 82.03 527.82 22.74' 505.08 PASS 1888.30 1711.77 137.24 -562.12 1697.25 T 1695.58 211.30 24.82 82.81 591.82 23.68 568.14 PASS 1900.00/. 1719.12 139.40 -570.96 1704.61 1702.59 213.53 24.73 82.91 600.52. 23.81 576.71 PASS 2000.00.} 1781.99 157.84 -646.51 1767.03 1761.77 233.36 24.10 83.58 675.16 24.82,650.34 PASS 2013.00 1790.16 160.24 -656.33 1775.10 1769.39 236.04 24.03 83.64 684.89 24.84 660.05 PASS 2100.00t 1846.57 175.66 -720.74 1830.72 1821.59 255.22 23.62 83.90 749.02 25.78 723.24 PASS 2200.00/. 1915.50 191.80 -791.34 1898.12 1884.26 280.01 23.21 83.82 819.91 26.93 792.99 PASS 2300.001. 1988.58 206.19 -858.05 1967.91 1948.38 307.56 22.82 83.44 887.60 28.14 859.46 PASS 2400.001. 2065.55 218.77 -920.61 2039.63 2013.39 337.83 22.46 82.81 951.99 29.37 922.62 PASS 2410.70 2074.00 220.01 -927.05 2048.62 2021.50 341.73 22.41 82.70 958.67 29.52 929.15 PASS €9 25 • • RB Clearance Report FARIIII Cook Inlet EnergyOlson2 rBAKER - - Closest estApproach Page 10 of 25 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WeMPlan Facility Olson Creek 1 I CLEARANCE DATA-Offset Wellbore:Olson 1 PB1 Offset Wdlpath:Olson 1 PB1 Facility:Olson Creek Slot:Olson 1 Slot Welt Olson 1 P21 Threshold Value0.00 ft t=interpolated/extrapolated statbn Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Hordz C-C ACR Ellipse ACR [ft] [ft] pt] [ft] [ft] 91] [[t] gt] Bearing Clear Dist MASD Sep Status M Ift] IR] <n] 2420.90 2082.06 221.19 -933.19 2057.21 2029.24 345.44 22.36 82.59. 965.04 29.67 935.37 PASS 2500.00} 2144.45 230.32 -980.95 2131.48 2096.60 376.69 21.56 81.691 1014.26 30.99 983.27 PASS 2600.00} 2223.33 241.87 -1041.32 2218.11 2176.34 410.51 19.92 80.971 107559' 32.581 1043.01 PASS 2700.00} 2302.21 253.42 -1101.70 2313.11 2264.88 444.88 17.71 80.30'. 1136271 34.387 1101.89 PASS 2800.00} 2381.08 264.97 -1162.07 2407.16 2353.72 475.57 14.85 79.86 119593 36.14 1159.79 PASS 2900.00} 2459.96 276.52 -1222.45 2501.22 2443.43 503.63 11.31 79.57 125459 37.87 1216.72 PASS 3000.00} 2538.83 288.07 -1282.82 2590.06 2528.79 5 27.9 8 7.79 79.47 1312.76 39.45 1273.31 PASS 3100.00} 2617.71 299.62 -1343.20 2677.61 2613.62 549.36 4.21 79.50 137036 40.92 1329.44 PASS 3200.00} 2696.59 311.17 -1403.57 2768.78 2702.59 568.88 0.64 79.60 1427.68 42.35 1385.33 PASS 3300.00} 2775.46 322.72 -1463.95 2861.17 2793.33 585.83 -3.23 79.79 148433 43.67 1440.66 PASS 3400.00} 2854.34 334.27 -1524.32 2956.81 2887.68 600.80 -7.59 80.03 154033 44.93 1495.40 PASS 3500.00} 2933.22 345.82 -1584.70 3050.15 2980.10 613.05 -12.13 80.36 1595.80 46.05 1549.75 PASS 3600.00} 3012.09 357.37 -1645.07 3125.59 3055.02 621.22 -15.69 80.80 1651.16 46.88 1604.28 PASS 3700.00} 3090.97 368.92 -1705.45 3200.11 3129.20 627.56 -18.50 81.28 1707.09 47.61 1659.48 PASS 3800.00} 3169.84 380.47 -1765.82 3275.13 3204.05 632.14 -20.72 81.79 1763.49 48.24 1715.25 PASS 3900.00} 3248.72 392.02 -1826.20 3346.74 3275.62 633.89 -22.33 82.36 1820.20 48.71 1771.49 PASS 4000.00} 3327.60 403.57 -1886.57 3425.73 3354.60 634.07 -23.59 82.95 187738 49.14 1828.25 PASS 4100.00} 3406.47 415.12 -1946.95 3505.71 3434.56 632.67 -24.60 83.54 1934.82 49.49 1885.34 PASS__ 4200.00} 3485.35 426.67 -2007.32 3592.58 3521.35 629.24 -25.92 84.16 1992.06 49.78 1942.27 PASS ' 4300.00} 3564.23 438.22 -2067.70 3662.70 3591.37 625.78 -26.77 84.75 2049.70 50.00 1999.70 PASS 4400.00} 3643.10 449.77 -2128.07 3735.59 3664.16 621.94 -27.36 85.32 2107.86 50.21 2057.65 PASS __4500.00} 3721.98 461.32 -2188.45 3800.32 3728.77 617.98 -27.52 85.85 2166.61 50.39 2116.22 PASS _4600.00} 3800.85 472.87 -2248.82 3887.74 3815.98 611.95 -27.62 86.42 222.5.60 50.60 2174.99 PASS 4700.00} 3879.73 484.42 -2309.20 3973.15 3901.20 606.17 -28.06 86.95 2284.48 50.84 2233.64 PASS S 4800.00} 3958.61 495.97 -2369.57 4052.73 3980.59 600.75 -28.50 87.44 234331 51.08 2292.43 PASS 4900.00} 4037.48 507.52 -2429.95 4131.14 4058.81 595.29 -29.00 87.91 2402.64 51.32 2351.32 PASS 5000.00} 4116.36 519.07 -2490.32 4215.61 4143.09 589.61 -29.62 88.36 2461.85 51.62 2410.24 PASS 5100.00} 4195.24 530.62 -2550.70 4298.67 4225.97 584.23 -30.46 88.78 2520.99 51.93 2469.06 PASS 5200.00} 4274.11 542.17 -2611.07 4390.65 4317.74 578.24 -31.63 89.20 2580.06 52.28 2527.78 PASS 5300.00} 4352.99 553.72 -2671.45 4479.68 4406.59 572.74 -33.28 89.59 2638.78 52.66 2586.12 PASS €8 26 • • lea Clearance Report Fait"! Olson Z`'e '#4BAKER Cook Inlet Energy Closest Approach Page 11 of 25 HES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WelPlan Facility Olson Creek CLEARANCE DATA-Offset Wellbore:Olson 1 PB1 Offset Wdlpath:Olson 1 PB1 Facility:Olson Creek Slot:Olson 1 Slat Welt Olson!PB1 Threshold Value=0.00 ft }=Interpolated/extrapolated station Ref MD Ref TVD Ref North Ref East Offset MI) Offset TVD Offset North Offset East Horiz C-C ACR Ellipse ACR [Ill [n] lit] 10] lit] [(t] [rt] [rt] Bearing Clear Dist MASD Sep Status P] [R] [ft] Ertl 5400.00} 4431.86 565.27 -2731.821 4569.04 4495.76 567.34 -35.19 89.96 269739 53.07 2644.32 PASS 5500.1011 4510.74 576.82 -2792.201 4640.88 4567.46 563.09 -36.89 90.29 2755.92 53.41 2702.51 PASS 5600.00} 4589.62 588.37 -2852.57 4727.06 4653.46 557.87 -38.75 90.62 2814.71 53.83 2760.88 PASS 5700.00} 4668.49 599.92 -2912.95.1' 4828.30 4754.47 551.69 -41.56 90.96 2873.07 54.33 2818.75 PASS 5800.00} 4747.37 611.47 -297332 4905.66 4831.63 546.70 -43.91 91.27 293133 54.72 2876.62 PASS 5900.00} 4826.25 623.02 -3033.70 5008.83 4934.53 540.05 -47.49 91.59 298932 55.24 2934.08 PASS , 6000.00} 4905.12 634.57 -3094.07 5089.39 5014.84 534.57 -50.55 91.88 3047.14 55.67 2991.47 PASS 6100.00} 4984.00 646.12 -3154.45 5183.44 5108.58 527.92 -54.33 92.18 3104.86 56.16 3048.70 PASS 6200.00} 5062.87 657.67 -3214.82 5288.16 5212.91 520.43 -59.31 92.49 3162.05 56.73 3105.32 PASS 6300.001- 5141.75 669.22 -3275.20 5377.49 5301.89 513.96 -63.86 92.77 3219.07 57.24 3161.83 PASS 6400.00} 5220.63 680.77 -3335.57 5477.89 5401.86 506.64 -69.64 93.05 327559 57.81 3217.77 PASS 6500.001- 5299.50 692.32 -3395.95:; 5533.00 5456.73 502.61 -72.87 93.27 3332.20 58.17 3274.03'',PASS 6600.00} 5378.38 703.87 -3456321 5533.00 5456.73 502.61 -72.87 93.40 339034 58.23 3332.11 PASS 6700.00} 5457.25 715.42 -3516.70 5533.00 5456.73 502.61 -72.87 93.54 345039 58.26 3392.13 PASS 6800.00} 5536.13 726.97 -3577.07 5533.00 5456.73 502.61 -72.87 93.66 3512.27 58.28 3453.99 PASS 6900.00} 5615.01 738.52 -3637.44 5533.00 5456.73 502.61 -72.87 93.79 3575.88 58.29 3517.59 PASS 7000.00} 5693.88 750.07 -3697.82 5533.00 5456.73 502.61 -72.87 93.91 3641.12 58.28 3582.84 PASS 7100.00} 5772.76 761.62 -3758.191 5533.00 5456.73 502.61 -72.87 94.02 370791 58.26 3649.65 PASS 7200.00} 5851.64 773.17 -3818.57 5533.00 5456.73 502.61 -72.87 94.13 3776.17 58.23 3717.93 PASS 7300.00} 5930.51 784.72 -3878.94 5533.00 5456.73 502.61 -72.87 94.24 3845.81 58.20 3787.62 PASS 7400.00} 600939 796.27 -3939.32 5533.00 5456.73 502.61 -72.87 94.34 3916.77 58.15 3858.62 PASS 7446.50 6046.07 801.64 -3967.39 5533.00 5456.73 502.61 -72.87 94.39 3950.20 58.13 3892.06 PASS 7500.00}j_ 6088.72 807.69 -3999.11 5533.00 5456.73 502.61 -72.87 94.44 3988.47 58.10 3930.36 PASS 7600.00f 6170.80 818.31 -4055.22 5533.00 5456.73 502.61 -72.87 94.53 4058.16 57.95 4000.21 PASS 7700.001- 62.55.76 828.01 -4107.05 5533.00 5456.73 502.61 -72.87 94.61 4125.40 57.86 4067.54 PASS 7777.90 6323.78 834.90 -4144.37 5533.00 5456.73 502.61 -72.87 94.67 4176.04 57.76 4118.28 PASS 7800.00} 6343.29 836.77 -4154.57 5533.00 5456.73 502.61 -72.87 94.68 4190.22 57.73 4132.49 PASS 7900.00} 6431.60 845.24 -4200.73 5533.00 5456.73 502.61 -72.87 94.75 4255.23 57.56 4197.68 PASS 8000.00} 6519.90 853.72 -4246.89 5533.00 5456.73 502.61 -72.87 94.81 432158 57.39 4264.19 PASS 8100.001- 6608.20 862.19 -4293.05 5533.00 5456.73 502.61 -72.87 94.87 4389.21 57.22 4331.98 PASS €8 27 • . cea Clearance Report FARO Cook Inlet EnergyOlson 2 rBAKER - Closest Approach Page 12 of 25 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WeilPlan Facility Olson Creek CLEARANCE DATA-Offset Wellbore:Olson 1 PB1 Offset Wdlpatle Olson 1 PB1 Facility:Olson Creek Slot:Olson 1 Slot Welk Olson 1 P51 Threshold Vatue=0.00 ft }=tuerpolatedlextrapolated station Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Hark C-C ACR Ellipse ACR 8t] pt] [cc) [tt] gt] [ft] [ft] [tt] Bearing Clear Dist MASD Sep Status I9 lit] [tt] Ft] 8200.00} 6696.51 870.66 -4339.21 5533.00 5456.73 502.61 -72.87 94.93, 4458.05 57.06 4400.98 PASS' 8300.001- 6784.81 879.13 -438.537 5533.00 5456.73 502.61 -72.87 9499 4528.05 56.91 4471.14 PASS 8400.00} 6873.111 887.60 -443133 5533.00 5456.73 502.61 -72.87 95 051 4599.17 56.76 4542.40 PASS 8500.00} 6961.41' 896.08 -4477.69 5533.00 5456.73 502.61 -72.87 95.10 4671.34 56.62 4614.72 PASS 8600.00} 7049.72 904.55 -4523.86 5533.00 5456.73 502.61 -72.87 95.16 474452 56.49 4688.03 PASS 8700.00} 7138.02 913.02 -4570.02 5533.00 5456.73 502.61 -72.87 9521 4818.66 5636 4762.30 PASS 8800.001- 7226.32 921.49 -4616.18 5533.00 5456.73 502.61 -72.871 95271 4893.73 56.25 4837.48 PASS 8900.00} 7314.63 929.96 -466234 5533.00 5456.73 502.61 -72.871 9532' 4969.67 56.14 4913.53 PASS 9000.00} 7402.93 938.44 -4708.50 5533.00 5456.73 502.61 -72.87 9537 5046.46 56.04 4990.41 PASS 9100.001 7491.23 946.91 -4754.66 5533.00 5456.73 502.61 -72.87 95.42 5124.04 5595 5068.09 PASS 9200.00} 7579.54 955.38 -4800.82 5533.00 5456.73 502.61 -72.87 95.47 520239 55.88 5146.51 PASS 9300.00} 7667.84 963.85 -4846.98 5533.00 5456.73 502.61 -72.87 95.52 5281.47 55.81 5225.66 PASS 9400.00} 7756.14 972.32 -4893.14 5533.00 5456.73 502.61 -72.871 95.57 5361.25 55.75 5305.49 PASS 9500.00} 7844.44 980.80 -493930 5533.00 5456.73 502.61 -72.87 95.61 5441.69 55.71 5385.99 PASS 9600.00} 7932.75 989.27 -4985.46 5533.00 5456.73 502.61 -72.87 95.66 5522.78 55.67 5467.11 PASS 9700.00} 8021.05 997.74 -5031.62 5533.00 5456.73 502.61 -72.87 95.70 5604.48 55.65 5548.83 PASS 9800.00} 8109.35 1006.21 -5077.78 5533.00 5456.73 502.61 -72.87 95.75 5686.76 55.64 5631.12 PASS 9900.00} 8197.66 1014.68 -5123.95 5533.00 5456.73 502.61 -72.87 95.79 5769.60 55.64 5713.96 PASS 10000.00} 8285.96 1023.16 -5170.11 5533.00 5456.73 502.61 -72.87 95.83 5852.98 55.65 5797.33 PASS 10100.00} 8374.26 1031.63 -521627 5533.00 5456.73 502.61 -72.87 95.87 5936.87 55.67 5881.20 PASS 10200.001 8462.56 1040.10 -5262.43 5533.00 5456.73 502.61 -72.87 95.91 602125 55.71 5965.54 PASS 10300.00 8550.87 1048.57 -530839 5533.00 5456.73 502.61 -72.87 95.95 6106.111 55.75 6050.35 PASS 10400.00 8639.17 1057.05 -5354.75 5533.00 5456.73 502.61 -72.87 95.99 6191.4-1.1 55.811 6135.60 PASS I 10500.00} 8727.47 1065.52 -540091r 5533.00 5456.73 502.61 -72.87 96.03 6277.15{ 55.88E 6221.28 PASS ' 10600.001 8815.78 1073.99 -5447.07 5533.00 5456.73 502.61 -72.87 96.07 636331 55.96 6307.35 PASS 10700.001 8904.08 1082.46 -549323 5533.00 5456.73 502.61 -72.87 96.11 6449.87 56.05 6393.82 PASS 10800.00} 8992.38 1090.93 -553939 5533.00 5456.73 502.61 -72.87 96.14 6536.81 56.15 6480.66 PASS 10900.00} 9080.69 1099.41 -558535 5533.00 5456.73 502.61 -72.87 96.18 6624.12 5626 6567.85 PASS 11000.00} 9168.99 1107.88 -5631.71 5533.00 5456.73 502.61 -72.87 9621 6711.78 5639 6655.39 PASS 11100.00} 9257.29 1116.35 -5677.87 5533.00 5456.73 502.61 -72.87 9625 6799.78 56.52 6743.26 PASS' €0 28 • ceB Clearance Report raiiis Cook Inlet EnergyOlson 2 rBAKER - Closest Approach Page 13 of 25 HUGHES REFERENCE WELLPATH IDENTIFICATIU\ Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) rWell Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek CLEARANCE DATA-Offset wellbore:Olson 1 P131 Offset Welpath:Olson 1 P131 Facility:Olson Creek Slot:Olson 1 Slot Welt Olson 1 PB1 Threshold Value 0.00 ft f=Interpolated/extrapolated statbn Ref MD Ref TVD Ref North Ref East Offset NII) Offset TVD Offset North Offset East Horn C-C ACR Ellipse ACR [n] [it] [n] [h] Qt] fit) rt] 3t] Bearing Clear Dist MASD Sep Status PI Lit] [ft) [RI 11200.00} 9345.59 1124.82 -5724.03 5533.00 5456.73 502.61 -72.87 9628 6888.11 56.67 6831.45 PASS 11300.00} 9433.90 1133.29 -5770.20 5533.00 5456.73 502.61 -72.87. 9632 6976.76 56.83 6919.93 PASS 11400.001. 9522.20 1141.77 -5816.36` 5533.00 5456.73 502.61 -72.871 9635; 7065.71 56.99 7008.72 PASS 11500.00} 9610.50 1150.24 -5862.52 5533.00 5456.73' 502.61 -72.87 9638 7154.95 57.17 7097.78 PASS 11600.00} 9698.81 1158.71 -5908.68 5533.00 5456.73 502.61 -72.87 96A2 7244.47 5736 7187.11 PASS 11700.00} 9787.11 1167.18 -5954.84 5533.00 5456.73 502.61 -72.87 96.45 7334.26 57.56 7276.71 PASS 11800.00} 9875.41 1175.65 -6001.00 5533.00 5456.73 502.61 -72.87 96.48 7424.32 57.77 7366.55 PASS 11900.00} 9963.72 1184.13 -6047.16 5533.00 5456.73 502.61 -72.87 9631... 7514.62 57.98 7456.64 PASS 11967.90 10023.67 1189.88 -6078.50 5533.00 5456.73 502.61 -72.87 96.53( 7576.08 58.14 7517.94 PASS POSITIONAL UNCERTAINTY- Offset Wellbore Olson 1 PB1 Offset Wellpath:Olson 1 PB1 Slot Surface Uncertainty @1SD Horizontal 2.00011 Vertical 1.000ft Facility Surface Uncertainty @1 SD Horizontal 20.00011 Vertical 3.000ft HOLE&CASING SECTIONS-Offset Welbare:Olson 1 PB1 Offset Wetlpath:Olson 1 PB1 String/Diameter Start MD End MD Interval Stat TVD End TVD StartN/S Stat FJW End NIS End E/W [it] [ft] [ft] [it] [ft] [ft] [n] lit] [ft] 10.75in Conductor 15.30 157.00 141.70 48.10 189.78 -3.35 18.89 -2.70 18.90 7.625in Caging 15.30 1998.00 1982.70 48.10 1991.07 -3.35 18.89 95.87, 16.36 6.75in Open Hole 15.30 5715.00 5699.70 48.10 NA -3.35 18.89 NA NA €3 29 • . ceB Clearance Report Irara. Olson 2 rBAKER _ Cook Inlet Energy Closestsest Approach Page 14 of 25 HES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy 'Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WeilPlan Facility Olson Creek WELLPATH COMPOSITION-Offset Wdtbore:Olson 1 PB1 (Offset Welipath Olson 1 PB1 Start MD End MD Positional Uncertainty Modal Log Nam&Conunent Wellbore [ft] [ft] 1530 1850.00 Generic p,'ro-continuous(Standard) Olson 1 PB1 Gyro<0-1850> Olson 1 PB1 1850.00 5533.00 ISCWSA MWD,Rev.2,axial magnetic correction(Standard) Olson 1 PB1 MWD<2037-5533> Olson 1 PB1 OFFSET WELLPATH MD REFERENCE- Offset Wetmore:Olson(PBI Offset t Wdlpath:Olson 1 PB1 MD Reference:Rig on Olson 1(RKB) Offiet TVD&kcal coorcanates use Reference Wellpath settings (See WELLPATH DATUMonpage 1 ofMis report) Ellipse Start MD 339.708 €1 30 i 0 ceB Clearance Report WARE Cook Inlet EnergyOlson 2 VeroBAKER Closest Approaa Cbch Page 15 of 25 HUGHES REFERENCE VGELLPATH IDENTIFICATION `,, Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek CLEARANCE DATA-Offset Wellbore:Otter#tA Offset Welputh:NoviTrak MWD<4436-7021'> Facility:Otter Slat Otter#1 Welt Otter#1 Threshold Vaal 10.00 ft t=intetpolated/extrapolated station Ref MD Ref TVD Ref North Ref East Offset NII) Offset TVD Offset North Offset East 13or¢ C-C ACE Ellipse ACR Ft] [ft] [R] pt] [n] [R] Ert] Ft] Bearing Clear Dist MASD Sep Status P] [ft] In] Ertl 0.00 0.00 0.00 0.00 0.00 149.15 26741.81 27608.57'' 45.91 38436.70 1.11 3843538 PASS 100.00t 100.00 0.00 0.00 0.00 149.15 26741.81. 27608.57 45.91 38436.44 1.11 3843532 PASS 1 160.001 160.00 0.00 0.00 10.00 _159.15 26741.81' 2760856 45.91 38436.41 1.11 38435.29 PASS 200.001 200.00 0.00 0.00 31.90 181.05 26741.85 27608.54 45.91 38436.42 1.11 3843530 PASS 300.001 300.00 0.00 0.00 94.63 ?' 3.78 26742.14 27608.34 45.91 38436.52 0.80 38435.71 PASS 400.001 400.00 0.00 0.00 157.35 306.49 26742.74 27607.93 45.91 38436.71 61.10 38375.61 PASS 500.00 500.00 0.00 0.00 229.59 378.73 26743.77 27607.23 45.911 384_37.00 61.10 38375.90 PASS 600.001 599.93 0.76 -3.12 322.09 471.20 26745.45 27606.02 45.91' 38439.03 61.11 38377.92 PASS 684.431 684.00 239 -1039 400.00 549.08 26747.14 27604.75 45.92 38443.42 121.44 38321.98 PASS 700.001 699.45 3.04 -12.45 412.14 561.22 26747.43 27604.53 45.92 38444.50 121.44 38323.05 PASS 800.001 798.15 6.83 -27.97 489.79 638.83 26749.33 27603.11 45.94. 38453.39 121.48 38331.91 PASS 900.001 895.62 12.11 -49.60 566.62 715.62 26751.36 27601.62 45.96' 38465.70 121.53 38344.16 PASS 1000.001 991.46 18.86 -7727 660.65 80939 26753.98'. 27599.71 45.991 38481.36 121.61 38359.75 PASS 1100.001 1085.28 27.06 -110.85 767.06 915.94 26756.99 27597.49 46.03 38500.25 121.71 38378.54 PASS 1200.001 1176.69 36.67 -15020 877.67 1026.48 26760.12 27595.11 46.08 38522.30 121.85 38400.45 PASS 1300.001 1265.31 47.65 -195.17 988.18 1136.92 26763.21 27592.68 46.13 38547.41 122.05 3842.536 PASS 1400.001 1350.78 59.95 -24536 1102.42 1251.08 26766.37 27590.12 46.19 38575.49122.32 38453.17 PASS 1500.001 1432.75 73.53 -301.18 1208.10 1356.69 26769.26 27587.68 46.25 38606.43; 122.68' 38483.75 PASS 1600.001 1510.88 8833 -361.79 1273.01 142137 26771.00 27586.21 46.33 38640.18 123.16 38517.02 PASS 1700.001 1584.84 10429 -427.15 1334.54 1483.06 26772.61 27584.88 46.41 38676.66 123.79 38552.87 PASS 1800.001 1654.34 12133 -496.97 1392.42 1540.91 26774.10 27583.69 46.49 38715.71 124.61 38591.11 PASS 1888.30 1711.77 137.24 -562.12 1480.57 1629.02 26776.28 27581.94 46.57 38752.20 125.54 38626.66 PASS 1900.001 1719.12 139.40 -570.96 1492.84_ 164128 26776.57 27581.69 46.58 38757.16 125.68 38631.481 PASS 2000.001 1781.99 157.84 -64631 1597.66, 1746.05 26778.99 27579.62 46.68 38799.50 126.96 38672.551 PASS 2013.00 1790.16 160.24 -65633 1607.62 1756.01 26779.21 27579.42 46.69 38805.01 127.03 38677.99 PASS 2100.001 1846.57 175.66 -720.74 1671.07 1819.43 26780.63 27578.16 46.77 38841.38 128.11 3871327 PASS 2200.001 1915.50 191.80 -79134 1748.47 1896.79 26782.39 27576.57 46.8.5 38881.85 129.47 3875239 PASS 2300.001 1988.58 206.19 -858.05 1831.76 1980.04 26784.32 27574.81 46.93 38920.74 130.76 38789.98 PASS 2400.001 2065.55 218.77 -920.61 1921.83 2070.06 26786.45 27572.82 47.00 38957.89 131.99 38825.90 PASS 2410.70 2074.00 220.01 -927.05 1931.72 2079.95 26786.68 27572.60 47.01 38961.75 132.11 38829.64 PASS €3 31 S • ceB Clearance Report Val-it'll Cook Inlet EnergyOlson 2 rBAKER Cbsest Approach Page 16 of 25 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well 1Ol on 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek CLEARANCE DATA-Offset Wellbore:Otter#1A Offset Wellpah:NavlTrat MWD<4436-7021'> Facility:Otter Slot:Otter#1 Well Otter#1 Threshold Vahte=0.00 ft t=Interpolatedleetrapolated statim Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Hort C-C ACR Ellipse ACR [ftl lttl lrtl [RI Ittl [<t] Rtl [rtl Bearing Clear Dist MASD Sep Status [9 [ItI [ft] [ft] 2420.90 2082.06 221.19 -933.19 1941.15 208937 26786910 27572.39' 47.02 38965.44 132.13 38833.21 PASS' 2500.001' 2144.45 23032 -980.95 2006.99' 2155.17 2678851 27570.88 47.07 38994.151 133.17 38860.98 PASS 2600.001' 2223.33 241.87 -104132 2052.58 2200.73, 26789.69 27569.78 47.14 39030.53] 13439 38896.14 PASS 2700.001- 2302.21 253.42 -1101.70 2098.27 2246.40 26791.00 27568.63 47.21 39067.04 135.65 38931.39 PASS 2800.001- 2381.08 264.97 -1162.07 2144.07 2292.16 26792.44 27567.42 47.28 39103.68 136.96 38966.73 PASS 2900.00} 2459.96 27652 -1222.45 2189.98 2338.02 26793.99 27566.15 4735 39140.45 138.30 39002.15 PASS 3000.001- 2538.83 288.07 -1282.82 2234.04 2382.04 26795.60 27564.89 47.42 39177.34 139.67 39037.67 PASS 3100.00} 2617.71 299.62 -1343.20 2277.64 2425.59 26797.29 27563.60 47.49 39214.36 141.08 39073.28 PASS 3200.00} 2696.59 311.17 -1403.57 2321.32 2469.20 26799.08 27562.27 47.56 39251.51 142.53 39108.99 PASS 3300.00} 2775.46 322.72 -146395 2365.06 2512.89 26800.99 27560.90 47.63 39288.79 144.00 39144.80 PASS 3400.00} 2854.34 33427 -152432 2423.12 2570.86 26803.66 27559.03 47.69 39326.20 145.51 39180.70 PASS 3500.00} 2933.22 345.821 4584.701 2512.73 2660.30 2680804 27555.881 47.76 39363.64 147.06 39216.58 PASS 3600.001' 3012.09 357371 -1645.07 2551.50 2699.00 26810.02 27554.481, 47.83 39401.19 148.61 39252.58 PASS 3700.00} 3090.97 368.92 -1705.45 2590.27 2737.69 26812.05 27553.08 47.89 39438.88 150.18 39288.69 PASS 3800.001' 3169.84 380.47 -1765.82 2614.20 2761.56 2681334 27552.21 47.96 39476.71 151.77 39324.94 PASS 3900.001. 3248.72 392.02 -1826.20 2633.16 2780.48 26814.41 27551.54 48.03 39514.72 153.37 39361.35 PASS_ 4000.00} 3327.60 403.57 -188657 2652.11 2799.39 2681551 27550.86 48.10 39552.90 154.99 39397.92 PASS 4100.001' 3406.47 415.12 -1946.95 2671.07 2818.30 26816.66 27550.19 48.17 39591.27 156.62 39434.65 PASS_ 4200.001' 3485.35 426.67 -200732 2690.03 2837.21 26817.85 27549.53 48.24 39629.81 158.27 39471.54 PASS 4300.00} 3564.23 43822 -2067.70 2705.48 2852.62 26818.85 27548.99 48.31 39668.52 159.94 3950839 PASS 4400.001' 3643.10 449.77 -2128.07 2717.03 2864.14 26819.62 27548.59 48.38 39707.43 161.61 39545.82 PASS 4500.00} 3721.98 461.32 -2188.45 2728.58 2875.65 2682041 27548.20 48.45 39746.53 163.30 39583.23 PASS 4600.00} 3800.8.5 472.87 -2248.82 2740.12 2887.16 2682123 27547.82 48.52 39785.81 165.00 39620.811 PASS` 4700.00} 3879.73 484.42 -2309.20 2751.66 2898.66 26822.08 27547.44 48.58 39825.28 166.71 39658.58:PASS 4800.00} 3958.61 49597 -236957 2763.19 2910.15 26822.94 27547.07 48.65 39864.94 168.43 39696.52 PASS 4900.00} 4037.48 50752 -2429.95 2774.72 2921.64 26823.83 27546.70, 48.72 39904.79 170.16 39734.64 PASS 5000.00} 4116.36 519.07 -249032 2786.24 2933.12 26824.74 27546.34 48.79 39944.83 171.89 39772.93 PASS 5100.00} 4195.24 530.62 -2550.70 2797.76 2944.59 2682.5.68 27545.98 48.86 39985.05 173.64 39811.41 PASS 5200.001- 4274.11 542.17 -2611.07 2811.91 2958.69 26826.86 27545.55 48.92 40025.46 175.40 39850.06 PASS 5300.00} 4352.99 553.72 -2671.45 2826.69 2973.41 26828.12 27545.11 48.99 40066.04 177.16 39888.8$= ASS'= €8 32 • • RR13 Clearance Report Ir'ilitIll Olson zroBAKER Cook Inlet Energy Closest Approach Page 17 of 25 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well rOlson 2 Field Olson Creek Unit Wellbore Olson 2 WeilPlan Facility Olson Creek f CLEARANCE DATA-Offset Wellbore:Otter#1A Offset Wapiti':NaviTrak MWD<4436-7021> Facility:Otter Slot Otter#1 Welk Otter#1 Threshold Vale 0.00 ft t=Interpolated/extrapolated statim Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Horrs C-C ACR Ellipse ACR [ft] pt] pt] [R] pt.] pt] [ft] [n] Hearing Clear DM MASD Sep Status 15 ln1 RL] Ft] 5400.00} 4431.86 565.27 -2731.82 2841.47 2988.13 26829.42 27544.68 49.06 40106.81 178.93 39927.87 PASS 5500.00t 4510.74 576.82 -2792.20 2856.24 3002.84 26830.74 27544.25 49.13 40147.75 180.71 39967.04 PASS 5600.00 4589.62 58837 -285237 2871.01 3017.54 26832.09 27543.82 49.19 40188.87 182.49 40006.37 PASS 5700.00 4668.49 599.92 -2912.95 2885.77 3032.22 26833.47 27543.41 49.26 40230.16 184.28 40045.88 PASS 5800.001 4747.37 611.47 -297332 2900.52 3046.90 26834.88 27543.00 4933 40271.63 186.07 40085.56 PASS 5900.001 4826.25 623.02 -3033.70 2915.17 3061.48 2683631 27542.60 49.39 40313.28 187.87 40125.41 PASS 6000.00} 4905.12 63437 -3094.07 2929.81 3076.04 26837.76 27542.21 49.46 40355.10 189.67 40165.43 PASS 6100.001 4984.00 646.12 -3154.45 2944.44 3090.59 26839.23 27541.84 49.53 40397.10 191.47 40205.63 PASS 6200.001 5062.87 657.67 -3214.82 2959.05 3105.11 26840.72 27541.48 49.59 40439.27 193.28 40245.99 PASS 6300.00t 5141.75 669.22 -3275.20 2973.64 3119.62 2684224 27541.13 49.66 40481.62 195.09 40286.53 PASS 6400.001 5220.63 680.77 -333557 2988.22 3134.12 26843.78 27540.79 49.72 40524.14 196.90 40327.24 PASS 6500.001 5299.50 69232 -3395.95 3003.16 3148.97 2684538 27540.45 49.79 40566.83 198.71 40368.12 PASS 6600.001 5378.38 703.87 -345632 3019.72 3165.43 26847.18 27540.09 49.86 40609.69 200.53 40409.16 PASS 6700.001 5457.25 715A2 -3516.70 3036.27 3181.87 26849.01 27539.73 49.92 40652.72 202.35 40450.37 PASS 6800.001 5536.13 726.97 -3577.07 3052.80 3198.29 26850.87 27539.39 49.99 40695.92 204.17 40491.75 PASS 6900.001 5615.01 73852 -3637.44 3069.32 3214.70 26852.77 27539.05 50.05 40739.28 206.00 40533.29 PASS 7000.001 5693.88 750.07 -3697.82 3085.83 3231.10 26854.68 27538.72 50.11 40782.81 207.82 40574.99 PASS 7100.00/. 5772.76 761.62 -3758.19 3101.91 3247.06 2685658 27538.41 50.18 40826.51 209.64 40616.87 PASS 7200.00/. 5851.64 773.17 -381857 3115.41 3260.46 2685820 27538.16 50.24 40870.37 211.46 40658.91 PASS 7300.001 5930.51 784.72 -3878.94 3128.90 3273.85 26859.84 27537.91 50.31 40914.41 213.28 40701.12 PASS 7400.001 6009.39 796/7 -393932 3142.38 3287.22 26861.50 27537.68 50.37 40958.61 215.10 40743.51 PASS 7446.50 6046.07 801.64 -396739 3148.64 3293.43 2686228 27537.58 50.40 40979.23 215.95 40763.28 PASS 7500.001- 6088.72 807.69 -3999.11 3155.91 3300.64 26863.19 27537.46 50.44 41002.65 216.90 40785.76 PASS 7600.001- 6170.80 81831 -405512 3169.85 3314.47 -2-4i864.95 27537.24 50.50 41044.72 218.44 40826.28 PASS 7700.00 t 6255.76 828.01 -4107.05 3184.22 3328.73 26866.79 27537.02 50.55 41084.47 219.90 40864.57 PASS 7777.90 6323.78 834.90 -414437 3195.69 3340.10 2686828 27536.86 50.59 41113.74 220.91 40892.83 PASS 7800.00/. 6343.29 836.77 -415437 3198.98 3343.35 26868.71 27536.82 50.60 41121.84 221.18 40900.65 PASS 7900.00/. 6431.60 84524 -4200.73 3212.94 3357.19 2687055 27536.63 50.65 41158.58 222.42 40936.17 PASS 8000.001 6519.90 853.72 -4246.89 3226.82 3370.95 26872.41 27536.46 50.70 41195.50 223.65 40971.86 PASS 8100.001 6608.20 862.19 -4293.05 3240.69 3384.69 2687429 27536.30 50.74 41232.61 224.88 41007.73 PASS €0 33 0 0 ceB Clearance Report FARO Olson 2r#4 BAKER _ Cook Inlet Energy Closest Approach Page 18 of 25 HES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 ______] Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek CLEARANCE DATA-Offset Wellbore:Otter#1A Offset Wd 1path:NaviTrak MWD<4436-7021'> Facility:Otter Slot•Otter#1 Welt Otter#1 Threshold Vaaie=0.00 ft f=Interpolated/extrapolated station Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Hark C-C ACR Ellipse ACR [ft] [ft] [ft] [ft] [ft] [ft] [ft] Pi Bearing Clear Dist MASD Sep Status n rti P] rtl 8200.001 6696.51 870.66 -4339.21 3254.54 3398.41 26876.19 27536.15 50.79 41269.89 226.111 41043.78 PASS 8300.00{ 6784.81 879.13 -4385.37 3268.38 3412.11 26878.12 27536.01 50.84 41307.35 22734 41080.01 PASS 8400.00/. 6873.11 887.60 -4431.53 3282.20 3425.79 26880.07 27535.89 50.89 41344.99 22837 41116.42 PASS_ 8500.00/. 6961.41 896.08 -4477.69 3296.01 3439.45 26882.04 27535.77 50.93 41382.80 229.80 41153.01 PASS 8600.00/. 7049.72 90455 -4523.86 7006.35 7134.37 2708658 2756591 50.79 41415.69 234.27 41181.42 PASS 8700.00f 7138.02 913.02 -4570.02 7021.00 7149.02 2708630 27566.10 50.84 41446.00 235.53 41210.47.PASS. 8800.00{- 7226.32 921.49 -4616.18 7021.00 7149.02 2708630 27566.10 50.89 41476.53 236.79 41239.741 PASS$ 8900.00{- 7314.63 929.96 -4662.34 7021.00 7149.02 2708630 27566.10 50.94 41507.27 238.04 41269.23 PASS 9000.00t 7402.93 938.44 -4708.50 7021.00 7149.02 2708630 27566.10 50.99 41538.24 239.29 41298.95 PASS 9100.001 7491.23 946.91 -4754.66 7021.00 7149.02 2708630 27566.10 51.04 41569.42 24054 41328.88 PASS 9200.00t 7579.54 95538 -4800.82 7021.00 7149.02 2708630 27566.10 51.09 41600.82 241.79 41359.03 PASS 9300.00f 7667.84 963.85 -4846.98 7021.00 7149.02 2708630 27566.10 51.13 41632.43 243.04 4138939 PASS' 9400.001 7756.14 97232 -4893.14 7021.00 7149.02 2708630 27566.10 51.18 41664.26 244.28 41419.98 PASS 9500.001 7844.44 980.80 -4939.30 7021.00 7149.02 2708630 27566.10 51.23 41696.31 24553 41450.78 PASS 9600.001 7932.75 98927 -4985.46 7021.00 7149.02 2708630 27566.10 51.28 4172837 246.77 41481.80 PASS 9700.00t 8021.05 997.74 -5031.62 7021.00 7149.02 2708630 27566.10 51.33 41761.05 248.01 41513.04 PASS 9800.001 8109.35 1006.21 -5077.78 7021.00 7149.02 2708630 27566.10 51.38 41793.74 24925 41544.49 PASS 9900.00/. 8197.66 1014.68 -5123.95 7021.00 7149.02 2708630 27566.10 51.43 41826.64 250.49 41576.15 PASS 10000.001 8285.96 1023.16 -5170.11 7021.00 7149.02 2708630 27566.10 51.48 41859.76 251.73 41608.03 PASS 10100.001 8374.26 1031.63 -5216.27 7021.00 7149.02 2708630 27566.10 51.52 41893.09 252.96 41640.13 PASS 10200.001 8462.56 1040.10 -5262.43 7021.00 7149.02 2708630 27566.10 51.57 41926.63 254.19 41672.44 PASS ) 10300.00t 8550.87 1048.57 -5308.59 7021.00 7149.02 2708630 27566.10 51.62 41960.38 255.43 41704.96 PASS ` 10400.00t 8639.17 1057.05 -5354.75 7021.00 7149.02 2708630 27566.10 51.67 41994.35 256.66 41737.69 PASS 10500.001 8727.47 1065.52 -5400.91 7021.00 7149.02 2708630 27566.10 51.72 42028.52 257.88 41770.64 PASS 10600.001 8815.78 1073.99 -5447.07 7021.00 7149.02 2708630 27566.10 51.76 42062.91 259.11 41803.80 PASS 10700.001 8904.08 1082.46 -5493.23 7021.00 7149.02 2708630 27566.10 51.81 42097.50 26033 41837.17 PASS 10800.00/. 8992.38 1090.93 -5539.39 7021.00 7149.02 2708630 27566.10 51.86 42132.30 26135 41870.75 PASS_ 10900.001 9080.69 1099.41 -5585.55 7021.00 7149.02 2708630 27566.10 51.91 42167.31 262.77 4190434 PASS_ 11000.00} 9168.99 1107.88 -5631.71 7021.00 7149.02 2708630 27566.10 51.96 42202.53 263.99 4193834 PASS 11100.00/. 9257.29 111635 -5677.87 7021.00 7149.02 2708630 27566.10 52.00 42237.96 26521 41972.75 PASS €8 34 I • cell Clearance Report Irtgi■ Olson Zpproa BAKER Cook Inlet Energy Closest Approach Page 19 of 25 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WeliPlan Facility Olson Creek CLEARANCE DATA-Offset Wellbore:Otter#IA Offset Wellpath:NaviTrak MWD<4436-7021'> Facility:Otter Slot Otter#1 Welk Otter#1 Threshold Vaite=0.00 ft t=intetpolated/extrapolated statim Ref AID Ref TVD Ref North Ref East Offset NII) Offset TVD Offset North Offset East Hartz C-C ACR Elipse ACR [ft] Rt] [it] ln1 [n] L<t] rt] [ft] Bearing Clear Dist MASD Sep Status P] Pt] [til Rt] 11200.00t 9345.59 1124.82 -5724.03 7021.00 7149.02 27086.30 27566.10 52.05 4227359` 266.42 42007.17 PASS 11300.001 9433.90 113329 -5770.20 7021.00 7149.02 2708630 27566.10 52.10 42309.43 267.63 42041.80 PASS 11400.0095 22.20 1141.77 -5816.36 7021.00 7149.02 2708630 27566.10 52.15 42345.48 268.84 42076.641 PASS 11500.001. 9610.50 1150.24 -5862.52 7021.00 7149.02 2708630 27566.10 52.19 42381.73 270.05 42111.68,PASS 11600.00/. 9698.81 1158.71 -5908.68 7021.00 7149.02 2708630 27566.10 52.24 42418.18 27125 42146.93 PASS 11700.00/. 9787.11 1167.18 -5954.84 7021.00 7149.02 2708630 27566.10 52.29 42454.84; 272.46 42182.39 PASS 11800.00t 9875.41 1175.65 -6001.00 7021.00 7149.02 2708630 27566.10 52.34 42491.71 273.66 42218.05 PASS 11900.00t 9963.72 1184.13 -6047.16 7021.00 7149.02 2708630 27566.10 52.38 42528.77 274.86 42253.92 PASS 11967.90 10023.67 1189.88 -6078.50 7021.00 7149.02 2708630 27566.10 52.41 42554.0C 275.67 42278.39 PASS POSITIONAL UNCERTAINTY- offset Wellbore:Otter#1A Offset Weilpath:NavlTrakMWD<4436-7021'> Slot Surface Uncertainty @1SD Horizontal 2.000ft Vertical 1.000ft Facility Surface Uncertainty @1SD Horizontal 20.000ft Vertical 3.000ft W ELLPATH COMPOSITION-Offset Wellbore:Otter#IA Offset Wellpath:NaviTrakMWD<4436-7021'> Start MD End MD Positional Uncertainty Model LogMane/Comment Wellbore [ft] [ft] 0.00 4400.00 Generic gyro-continuous(Dtillpipe) Otter#1 OMS(200-5686) Otter#1 4400.00 7021.00 NaviTrak(Standard) NaviTrak MWD<4436-7021'> Otter#1A OFFSET WELLPATH MD REFERENCE- Offset Wellbore:Otter#1A Offset Wdlpath:NaviTrakMWD<4436-7021'> MD Reference:Miller Rig#34(RTE) rOfet TVD&local coordinates we Refrrence Weltprgh settings (See WELLPATH DATUMon page 1 of this report) Ellipse Start MD 324.40ft €5 35 0 • ceB Clearance Report FARO Olson 2pproa BAKER Cook Inlet Energy Closest Approach Page 20 of 25 HES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot Olson 2 Slot - v Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek CLEARANCE DATA-Offset Wellbore:Otter#1 Offset Wellpath:Otter#1<0-5686> Facility:Otter Slat:Otter#1 Well Otter#1 Threshold Valle=0.00 ft t=lnterpolatedrextrapolated statim Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Horia C-C ACR Ellipse ACR Ft] pt] [R] [it] [ft] [1t] (it] Ertl Bearing Clear Dist MASD Sep Status 11 [ft] Ft] 151 0.00 0.00 0.00 0.00 0.00 149.15 26741.81' 27608.57' 45.91 38436.70 1.01 38435.69 PASS 100.001 100.00 0.00 0.00 0.00 149.15 26741.81 27608.57 45.91 38436.44 1.01 38435.43 PASS 160.001 160.00 0.00 0.00 10.00 159.15 26741.81 27608.56 45.91 38436.41 1.01 38435.40 PASS 200.001 200.00 0.00 0.00 31.90 181.05 26741.85 27608.54 45.91 38436.42 1.01 38435.41 PASS 300.001 300.00 0.00 0.00 94.63 243.78 26742.14 27608.34 45.91 38436.52 0.85 38435.67 PASS 400.001 400.00 0.00 0.00 157.35 306.49 26742.74 27607.93 45.91 38436.71 60.99 38375.72 PASS 500.00 500.00 0.00 0.00 229.59 378.73 26743.77 27607.23 45.91 38437.00 60.99 38376.01 PASS 600.001 599.93 0.76 -3.12 322.09 47120 26745.45 27606.02 45.91 38439.03 61.00 38378.03 PASS 684.43t 684.00 259 -10.59 400.00 549.08 26747.14 27604.75 45.92 38443.42 121.33 38322.09 PASS 700.00f 699.45 3.04 -12.45 412.14 561.22 26747.43 27604.53 45.92 38444. 38323.16 PASS 800.001 798.15 6.83 -27.97 489.79 638.83 26749.33 27603.11 45.94 38453.39'.. 121.37: 38332.02 PASS 900.001 895.62 12.11 -49.60 566.62 715.62 26751.36 27601.62 45.96 38465.70 121.42 38344.27 PASS 1000.001 991.46 18.86 -7727 660.65 80959 26753.98 27599.71 45.99 38481.36 121.50 38359.86 PASS 1100.001 1085.28 27.06 -110.85 767.06 915.94 26756.99 27597.49 46.03 38500.25 121.60 38378.65 PASS 1200.001 1176.69 36.67 -15020 877.67 1026.48 26760.12 27595.11 46.08 38522.30 121.74 3840036 PASS 1300.001 1265.31 47.65 -195.17 988.18 1136.92 26763.21 27592.68 46.13 38547.41 121.94 38425.47 PASS 1400.001 1350.78 59.95 -24556 1102.42 1251.08 26766.37 27590.12 46.19 38575.49 122.21 3845328 PASS 1500.00f 1432.75 7353 -301.18 1208.10 1356.69 26769.26 27587.68 46.25 38606.43 122.57 38483.86 PASS_ 1600.001 1510.88 8833 -361.79 1273.01 1421.57 26771.00 27586.21 46.33 38640.18 123.05 38517.13 PASS 1700.001 1584.84 10429 -427.15 1334.54 1483.06 26772.61 27584.88 46.41 38676.66 123.68 38552.98 PASS 1800.001 1654.34 12133 -496.97 1392.42 1540.91 26774.10 27583.69 46.49 38715.71 124.50 3859122 PASS 1888.30 1711.77 13724 -562.12 1480.57 1629.02 26776.28 27581.94 46.57 38752.20 125.43 38626.77 PASS E1900.001 1719.12 139.40 -570.96 1492.84 1641.28 26776.57 27581.69 46.58 38757.16 125.57 38631.58 PASS 2000.001 1781.99 157.84 -64631 1597.66 1746.05 26778.99 27579.62 46.68 38799.50 126.85 38672.65 PASS 2013.00 1790.16 16024 -65633 1607.62 1756.01 26779.21 27579.42 46.69 38805.01 126.92 38678.09 PASS 2100.001 1846.57 175.66 -720.74 1671.07 1819.43 26780.63 27578.16 46.77 38841.38 128.11 3871327 PASS 2200.001 1915.50 191.80 -79134 1748.47 1896.79 26782.39 27576.57 46.85 38881.85 129.47 3875239 PASS 2300.001 1988.58 206.19 -858.05 1831.76 1980.04 26784.32 27574.81 46.93 38920.74 130.76 38789.98 PASS 2400.001 2065.55 218.77 -920.61 1921.83 2070.06 26786.45 27572.82 47.00 38957.89 131.99 38825.90 PASS 2410.70 2074.00 220.01 -927.05 1931.72 2079.95 26786.68 27572.60 47.01 38961.75 132.11 38829.64 PASS €6 36 • 0 ceJ Clearance Report IrakII Cook Inlet EnergyOlson 2 BAKER Closed Approach Page 21 of 25 HUGHES 1a1'1:RE\('E \\EFFP 1.Ill ll)E.A 11 VICATION Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 We lPlan Facility Olson Creek CLEARANCE DATA-Offset Wellb ore:Otter#1 Offset Wdlpath Otter#1<0-5686> Facility:Otter Slot Otter#1 Welt Otter#1 Threshold Yalu t0.00 ft }=Interpolated/extrapolated station Ref NII) Rd TVD Rd North Ref East Offset MD OffsetTVD Offset North Offset East Noris C-C ACR Ellipse ACR [ft] 8t] Pt] [rt] 911 Inl [n] [1t] Bearing Clear Dist MASD Sep Status P] [ft] 8t] [ft] 2420.90 2082.06 221.19 -933.19 1941.15 2089.37 26786.91 27572.39 47.02 38965.44 132.23 38833.21 PASS 2500.00} 2144.45 23032 -980.95 2006.99 2155.17 .26788.5 1 27570.88 47.07 38994.15 133.17 38860.98 PASS 2600.00} 2223.33 241.87 -104132 2052.58 2200.73 26789.69 27569.78 47.14 39030.53 134.39 38896.14 PASS 2700.00} 2302.21 253.42 -1101.70 2098.27 2246.40 26791.00 27568.63 47.21 39067.04 135.55 38931.49 PASS 2800.00} 2381.08 264.97 •1162.07 2144.07 2292.16 26792.44 27567.42 47.28 39103.68 136.85 38966.83 PASS 2900.00} 2459.96 27652 -1222.45 2189.98 2338.02 26793.99 27566.15 47.35 39140.45 138.19 39002.25 PASS 3000.00} 2538.83 288.07 -1282.82 2234.04 2382.04 26795.60 27564.89 47.42 39177.34 139.57 39037.77 PASS 3100.00} 2617.71 299.62, -1343.20 2277.64 2425.59 2679729 27563.60 47.49 39214.36 140.98 39073.38 PASS 3200.00} 2696.59 311.17 -140357 2321.32 2469.20 26799.08 27562.27 47.56 39251.511 142.42. 39109.09 PASS 3300.00} 2775.46 446395 2365.06 2512.89 2680099 27560.90 47.63 392811.7.?1019 39144.90 PASS 3400.00} 2854.34 33427 -152432 2423.12 2570.86 26803.66 27559.03 47.69 39326.20 145.40 39180.80 PASS 3500.00} 2933.22 345.82 _-1584.70 2512.73 2660.30 26808.04 27555.88 47.76 39363.64 146.96 39216.69 PASS 3600.00} 3012.09 35737 -1645.07 2551.50 2699.00 26810.02 27554.48 47.83 39401.19 148.51 392.52.68 PASS 3700.00} 3090.97 368.92 -1705.45 2590.27 2737.69 26812.05 27553.08 47.89 39438.88 150.08 39288.80 PASS 3800.00} 3169.84 380.47 -1765.82 2614.20 2761.56 2681334 27552.21 47.96 39476.71 151.66 39325.05 PASS 3900.00} 3248.72 392.02 -182620 2633.16 2780.48 26814.41 27551.54 48.03 39514.72 153.261 39361.46 PASS 4000.00} 3327.60 403.57 -188657 2652.11 2799.39 26815.51 27550.86 48.10 39552.90 154.881 39398.02 PASS 4100.00} 3406.47 415.12 -1946.95 2671.07 2818.30 26816.66 27550.19 48.17 39591.27 156.52 39434.75 PASS 4200.00} 3485.35 426.67 -200732 2690.03 2837.21 26817.85 27549.53 48.24 39629.81 158.17 39471.64 PASS 4300.00} 3564.23 43822 -2067.70 2705.48 2852.62 26818.85 27548.99 4831 39668.52 159.83 39508.69 PASS 4400.00} 3643.10 449.77 -2128.07 2717.03 2864.14 26819.62 27548.59 48.38 39707.43 161.51 39545.92 PASS 4500.00} 3721.98 46132 -2188.45 2728.58 2875.65 26820.41 27548.20 48.45 39746.53 163.19 39583.33 PASS 4600.00} 3800.85 472.87 -2248.82 2740.12 2887.16 2682123 27547.82 48.52 39785.81 164.89 39620.92 PASS 4700.00} 3879.73 484.42 -2309.20 2751.66 2898.66 26822.08 27547.44 48.58 39825.28 166.60 39658.68 PASS 4800.00} 3958.61 495.97 -2369.57 2763.19 2910.15 26822.94 27547.07 48.65 39864.94 168.32 39696.62 PASS 4900.00} 4037.48 507.52 -2429.95 2774.72 2921.64 26823.83 27546.70 48.72 39904.79 170.05 39734.74 PASS 5000.00} 4116.36 519.07 -249032 2786.24 2933.12 26824.74 27546.34 48.79 39944.83 171.79 39773.04 PASS 5100.00} 4195.24 530.62 -2550.70 2797.76 2944.59 26825.68 27545.98 48.86 39985.05 173.54 39811.51 PASS 5200.00} 4274.11 542.17 -2611.07 2811.91 2958.69 2.6826.86 27545.55 48.92 40025.46 175.29 39850.16 PASS 5300.00} 4352.99 553.72 -2671.45 2826.69 2973.41 26828.12 27545.11 48.99 40066.04 177.06 39888.98 PASS €0 37 • • Clearance Report FARE Cook Inlet EnerOlson 2 rBAKER _ Energy Closest Approach Page 22 of 25 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy ,Slot [Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WeIPlan Facility Olson Creek CLEARANCE DATA-Offset Weill)ore:Otter#1 Offset Wdlpath:Otter#1<0-5686> Facility:Otter Slot Otter#1 Well Otter#1 Threshold Value-0.00 ft }=interpolated/extrapolated station Ref MI) Ref TVD Ref North Ref East Offset34D Offset TVD Offset North OffsetEaa Hartz C-C ACR Ellipse 1 ACR [ft] PI L<y lftl Gtl Ft] Iftl [ft] Bearing Clear Dig MASD Sep Status P] Ft] [ft] [ft] 5400.00} 4431.86 56527 -2731.82 2841.47 2988.13 26829.42 27544.66 49.06 40106.81 178.83 39927.98 PASS 5500.00} 4510.74 576.82 -2792.20 2856.24 3002.84 26830.74 27544.25 49.131 40147.75 180.61 39967.14,PASS 5600.00} 4589.62 58837 -285237 2871.01 3017.54 26832.09 27543.82 49.19 40188.87 182.39 40006.48 PASS 5700.00} 4668.49 599.92 -2912.95 2885.77 3032.22 26833.47 27543.41 49.26 40230.16 184.18 40045.99 PASS 5800.00} 4747.37 611.47 -297332 2900.52 3046.90 26834.88 27543.00 49.33 40271.63 185.97 40085.66 PASS 5900.00} 4826.25 623.02 -3033.70 2915.17 3061.48 26836.31 27542.60 49.39 40313.28 187.77 40125.52 PASS 6000.00} 4905.12 63437 -3094.07 2929.81 3076.041 26837.76 27542.21 49.46 40355.10 189.57 40165.54 PASS 6100.00} 4984.00 646.12 -3154.45 2944.44 3090.59 2_683923 27541.84 49.53 40397.10 191.37 40205.73 PASS 26 6200.001- 5062.87 657.67 -3214.82 2959.05 3105.11 840.72 27541.48 49.59 40439.27 193.18 40246.10 PASS 6300.00} 5141.75 66922 -327520 2973.64 3119.62 2684224 27541.13 49.66 40481.62 194.98 40286.64 PASS 6400.00} 5220.63 680.77 -333557 2988.22 3134.12 26843.78 27540.79 49.72 40524.14 196.80 40327.34 PASS I6500.00} 5299.50 69232 -3395.95 3003.16 3148.97 2684538 27540.45 49.79 40566.83 198.61 40368.22 PASS 1 6600.00} 5378.38 703.87 -345632 3019.72 3165.43 26847.18 27540.09 49.86 40609.69 200.43 40409.26 PASS 6700.00} 5457.25 715.42 -3516.70 3036.27 3181.87 26849.01 27539.73 49.92 40652.72 202.25 40450.47 PASS 6800.00} 5536.13 72697 -3577.07 3052.80 3198.29 26850.87 2753939 49.99 40695.92 204.07 40491.85 PASS 6900.00} 5615.01 73852 -3637.44 3069.32 3214.70 26852.77 27539.05 50.05 40739.28 205.89 40533.39 PASS 7000.00} 5693.88 750.07 -3697.82 3085.83 3231.10 26854.68 27538.72 50.11 40782.81 207.71 40575.10 PASS 7100.00} 5772.76 761.62 -3758.19 3101.91 3247.06 2685658 27538.41 50.18 40826.51 209.54 40616.97 PASS 7200.00} 5851.64 773.17 -381857 3115.41 3260.46 26858.20 27538.16 50.24 40870.37 211.36 40659.01 PASS 7300.00} 5930.51 784.72 -3878.94 3128.90 3273.85 26859.84 27537.91 5031 40914.41 213.18 40701.23 PASS 7400.00} 6009.39 796.27 -393932 3142.38 3287.22 2686130 27537.68 50.37 40958.61 215.00 40743.61 PASS' 7446.50 6046.07 801.64 -396739 3148.64 3293.43 26862.28 27537.58 50.40 40979.23 215.85 40763.38 PASS 7500.00} 6088.72 807.69 -3999.11 3155.91 3300.64 26863.19.. 27537.46 50.44 41002.65 216.79 40785.86 PASS 7600.001- 6170.80 81831 -4055.22 3169.85 3314.47 2686495. 27537.24 50.50 41044.72 218.34 40826.39 PASS 7700.00} 6255.76 828.01 -4107.05 3184.22 3328.73 26866.79 27537.02 50.55 41084.47 219.79 40864.67 PAS 7777.90 6323.78 834.90 -414437 3195.69 3340.10 2686828 27536.86 50.59 41113.74 220.81 40892.94 PASS 7800.00} 6343.29 836.77 -415457 3198.98 3343.3.5 26868.71 27536.82 50.60 41121.84 221.08 40900.76 PASS 7900.00} 6431.60 84524 -4200.73 3212.94 3357.19 2687055 27536.63 50.65 41158.58. 222.31 40936.27 PASS 8000.001- 6519.90 853.72 -4246.89 3226.82 3370.95 26872.41 27536.46 50.70 41195.501 223.54'_ 40971.96 PASS 8100.001- 6608.20 862.19 4293.05 3240.69 3384.69 2687429 27536.30 50.74 41232.61 224.77 41007.83 PASS 38 • • cea Clearance Report FA.. Cook Inlet EnergyOlson 2 rBAKER - - Closest Approach Page 23 of 25 HUGIFIES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy ;Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WeIPlan Facility Olson Creek CLEARANCE DATA-Offset Wellbore:Otter#1 Offset Wdlpath Otter#1<0-5686> Facility:Otter Slot:Otter#1 Well Otter#1 Threshold Value=0.00 ft t=Werpolatedlextrapolated statim Ref MD Ref TVD Rd North Rd East Offset MD Offset TVD Offset North Offset East Hork C-C ACR Ellipse ACR [ft] [n] [R] [ft] [ft] [ft] [R] [0] Bearing Clear Dist MASD Sep Status P1 pi [ft] [ft] 8200.001- 6696.51 670.66 -4339.21 3254.54 3398.41 26876.19' 27536.15 50.79 41269.89 226.00 41043.88 PASS 5300.00} 6784.81 879.13 -4385.37 3268.38 3412.1126878.12 27536.01 50.84 41307.35 22723 41080.11 PASS 8400.00} 6873.11 887.60 -4431.53 3282.20 3425.79 26880.07 27535.89 50.89 41344.99 228.46 41116521 PASS 8500.001. 6961.41 896.08 -4477.69 3296.01 3439.45 26882.04 27535.77 50.93 41382.80 229.69 41153.111 PASS 8600.00} 7049.72 90455 -4523.86 3311.36 3454.65 2688426 27535.66 50.98 41420.80 23092 41189.87 PASS 8700.00} 7138.02 913.02 -4570.02 3327.33 3470.44 2688659 2753556 51.03 41458.96 232.15 41226.81 PASS 8800.00} 7226.32 921.49 -4616.18 3343.28 3486.22 2688895 27535.47 51.07 41497.30 23338 41263.92 PASS 8900.00} 7314.63 929.96 -4662.34 3359.20 3501.96 26891.32 27535.40 51.12 41535.80 234.61 4130120 PASS 9000.00} 7402.93 938.44 -4708.50 3375.11 3517.69 26893.72 2753535 51.17 41574.481 235.84 41338.65 PASS 9100.001. 7491.23 94691 -4754.66 3390.99 3533.38 26896.13 2753532 51.21 4183:.237.06 4137627 PASS 9200.00} 7579.54 95538 -4800.82 3407.67 3549.86 26898.69 2753530 51.26 41652.35 238.29 41414.06 PASS 9300.00} 7667.84 963.85 -4846.98 3425.39 3567.38 26901.44 2753529 51.31 41691.54 23952 41452.02 PASS 9400.001. 7756.14 97232 -4893.14 3443.10 3584.86 2690411 2753531 51.35 41730.89 240.74 41490.14 PASS 9500.00} 7844.44 980.80 -4939.30 3460.78 3602.32 26907.01 2753534 51.40 41770.40 24197 41528.43 PASS 9600.00} 7932.75 98917 -4985.46 3478.43 3619.75 26909.82 2753539 51.44 41810.08 243.19 41566.89 PASS 9700.00} 8021.05 997.74 -5031.62 3496.06 3637.15 26912.66 27535.45 51.49 41849.92 244.42 41605.51 PASS 9800.00} 8109.35 100621 -5077.78 3555.38 3695.68 2692228 27535.72 51.53 41889.90 245.72 41644.17 PASS 9900.001. 8197.66 1014.68 -5123.95 3623.66 3763.05 2693336 27536.04 51.57 41929.92 247.04 41682.88 PASS 10000.00} 8285.96 1023.16 -5170.11 3686.97 3825.52 26943.64 27536.40 51.60 41970.02 24836 41721.66 PASS 10100.001- 8374.26 1031.63 -5216.27 3828.92 3965.63 26966.43 27537.30 51.63 42010.07 249.83 4176024 PASS 10200.00} 8462.56 1040.10 -5262.43 3891.38 4027.31 2697626 27537.84 31.67 42050.13 251.15 4179898 PASS 10300.00} 8550.87 1048.57 -5308.59 4161.59 4294.42 27016.96 27540.77 51.67 42089.84 25290 41836.94 PASS 10400.00} 8639.17 1057.05 -5354.75 4203.51 4335.86 27023.24 2754120 51.71 42129.62 254.18 41875.45 PASS 10500.00} 8727.47 106552 -5400.91 4271.83 4403.39 2703355 2754192 51.75 42169.49 25551 41913.98 PASS 10600.00} 8815.78 1073.99 -5447.07 4335.52 4466.35 27043.19 27542.60 51.79 42209.42 256.84 4195238 PASS 10700.00} 8904.08 1082.46 -5493.23 4395.93 4526.05 2705239 27543.26 51.83 42249.42 258.16 4199126 PASS 10800.00} 8992.38 1090.93 -5539.39 4439.71 4569.32 27059.05 27543.78 51.87 42289.51 259.44 42030.07 PASS 10900.001. 9080.69 1099.41 -5585.55 4482.16 4611.28 27065.47 2754438 51.91 42329.71 260.72 4206899 PASS 11000.00} 9168.99 1107.88 -5631.71 4713.91 4840.39 27100.15 27547.66 51.93 42369.87 262.44 42107.43 PASS 11100.00} 9257.29 111635 -5677.87 4751.29 4877.35 27105.75 27548.13 51.97 42409.90 263.71 42146.19 PASS €0 39 1 • 0 cell Clearance Report Irak■ Cook Inlet EnergyOlson 2 rBAKER Closest Approach Page 24 of 25 HUGHES REFERENCE\\'ELLP:ATH'DENT IFI('A1 ION Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellb ore Olson 2 WeilPlan Facility Olson Creek CLEARANCE DATA-Offset Wellbore:Otter#1 Offset Wdlpath:Otter#1<0-5686> Facility:Otter Slot Otter#1 Welt Otter#1 Threshold VaWe=0.00 ft t=lnterpolated/eatrapolated station Ref MD Rd TVD Ref North Ref East Offset MID Offset TVD Offset North Offset East Horh C-C ACR Ellipse ACR [ft] [rt] [ft] [rt] [it] [;t] [it] [ft] Bearing Clear DM MASD Sep Status P1 [ft] [ft] D't] 11200.00} 9345.59 1124.82 -5724.03 4788.64 4914.26 27111.42 27548.58 52.01 42450.05 264.98 42185.07'PASS 11300.00} 9433.90 1133.29 -5770.20 4869.58 4994.24 27123.79 27549.60 52.05 42490.30 26636 42223.93 PASS 11400.00} 9522.20 1141.77 -5816.36 4970.98 5094.47 27139.13 27550.97_ 52.08 4253033 267.79 42262.74 PASS 11500.00} 9610.50 1150.24 -5862.52 5088.54 5210.67 27156.88 27552.51 52.11 42570.74 269.26 42301.48 PASS 11600.00} 9698.81 1158.71 -5908.68 5133.74 5255.33 27163.78 27553.04 52.15 4261097 270.56 42340.41 PASS 11700.00} 9787.11 1167.18 -5954.84 5170.91 5292.05 27169.58 27553.44 52.19 4265132 271.83 42379.49 PASS, 11800.00}I 9875.41 1175.65 -6001.00 5204.65 5325.36 27174.93 27553.78 52.23 42691.79 273.09 42418.69 PASS I 11900.00} 9963.72 1184.13 -6047.16 5226.05 5346.48 2717838 27553.99 52.27 4273239 27433 42458.07 PASS 11967.90 10023.67 1189.88 -6078.50 5240.56 5360.80 27180.75 27554.13 52.30 42760.05 275.16 42484.89 PASS POSITIONAL UNCERTAINTY- Offset Wellbore•.Otter#1 Offset Wdlpath:Otter#1<0-5686> Slot Surface Uncertainty @1 SD Horizontal 2.000ft Vertical 1.000ft Facility Surface Uncertainty @1SD Horizontal 20.000ft Vertical 3.000ft HOLE&CASING SECTIONS-Offset Wdlb are:Otter#1 Offset Wellp ath:Otter#1<0-5686> Siring/Diameter Start MI) End MI) Interval Start TVD End TVD Start WS I[ Stat E/W End N/S 1. End ESV [n] [n] [n] [ft] [n] [ft] [n] at] [It] 10.75in Conductor 0.00 157.00 157.00 149.15 306.14 16301.71 16830.08 16301.99 16829.89 lin Casing 0.00 2092.00 2092.00 149.15 2240.13 16301.71 16830.08 16316.65 16817.96 4.Sin Casing 0.00 5686.00 5686.00 149.15 5798.95 16301.71 16830.08 16459.92 16814.22 €2 40 0 • era Clearance Report Valli Olson 2 vela BAKER Cook Inlet Energy Closeststseat Approach Page 25 of 25 HUGHES I , .a{ .zlitiltAW,.TIOr Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek WELLPATH COMPOSITION-Offset Wellbore:Otter#1 Offset Wellpnth:Otter#1<0-5686> Start MD End MD Positional Uncertainty Model Log Name/Comment Wellbore [ft] [ft] — 0.00 5686.00 Generic gyro-continuous(Drillpipe) Otter#1 GMS(200-5686) Otter#1 OFFSET WELLPATH MD REFERENCE- Offset Wellbore Otter#1 Offset Weupath:Otter#1<0-5686> !MD Reference:Miller Rig#34(RTE) Offset TVD&local coordinates use Retrence Wellpdh settings (See WELLPATH DATUMon page 1 of this report) Ellipse Start MD 324.408 €8 41 • • Olson Creek 2 Analysis General Geology The Olson Creek area is situated along the west/northwest flank of the Upper Cook Inlet Basin. The northeast trending structure appears to be set up along a northeast trending fault system, likely of transpressional origin, which is responsible for the development of the Three Mile Creek Field to the south-west of the Olson Creek prospect. This unnamed fault system is parallel and subordinate to the Bruin Bay Fault located further to the West/Northwest of the location area, and is generally considered the principal basin bounding fault in this portion of the basin. West of the Bruin Bay Fault,the Tertiary section of interest thins substantially. The sandstones of the Beluga and Tyonek Fms were deposited in a variety of continental depositional systems, ranging from anastomozing stream channels and alluvial fan complexes, to axial meandering to braided fluvial environments. The provenance area is characterized by a magmatic arc; which contributed an immature quartz+feldspar+volcanic lithic assemblages. The formations expected at the Olson Creek Location are as follows: • Sterling Fm. (Late Miocene) If present, it may be very thin. Porosities range from 25- 30%, with permeabilities — 100-500 md; The formation contains abundant volcanic rock fragments sourced from west; Mainly contains biogenic gas from interbedded coals; lower contact unconformable; Capped by glacial alluvium, so top seal can be an issue. • Beluga Fm. (Late Miocene) Porosities range from 17-24%, with permeabilities —50-400 md; Mainly claystones with interbedded sandstones, occasional gravels and lots of thin coals; usually contains biogenic gas from interbedded coals; Sands deposited in streams channels. • Tyonek Fm. (Early Oligocene — Late Miocene) Porosities range from 14-21%, with permeabilities from—40-100 md. Rocks were deposited in series of anastomozing stream channels with more and thicker coals than overlying Beluga Fm; Tyonek usually contains biogenic gas from coals. The Olson Creek 2 is expected to drill and test potential sands in the Beluga Fm. and to the base of the Tyonek Fm., gas prone formations in this area of onshore Cook Inlet. It will not penetrate the lower Chickaloon Fm. Surrounding fields such as the Beluga Field (East of Olson Creek), Lewis River(NE of Olson Creek), Three Mile Creek(SW of Olson Creek),Theodore River(ENE of Olson Creek) and Lone Creek Field (SW of Olson Creek) all produce gas in the Beluga Fm. with no liquid hydrocarbons encountered. There have been no liquid hydrocarbons encountered or tested in the Tyonek Fm. in wells that have penetrated to this horizon in this area. 42 0 0 Geologic Hazards The Olson Creek 1 well penetrated the Beluga Fm. down to 5,700' and did not encounter any appreciably gas or over-pressured sands. Seismic over the structure does not indicate the presence of shallow gas(see seismic line over well location—Confidential). The Olson Creek 2 well is to spud within 100' of the Olson Creek 1 well. Coals present in Beluga and Tyonek Fms that tend to slough off and swell into the well bore and are responsible for numerous stuck bits in previous wells. Care will be exercised for sloughing coals, differential sticking and/or lost circulation when drilling the Beluga and Tyonek Fms. Formation Tops (Estimated) Lower Sterling -200' and (Depths Estimated) Beluga 2,420" and/2,082' tvd (Depths Estimated) Upper Tyonek 7,820' and /6,345' tvd (Depths Estimated) Chickaloon —9,350' and/7,800' tvd (Depths Estimated) Logging Services: Mud Logging services will be done by Canrig and commence after conductor pipe has been set(Gas detection to TD of well). 2 sets of dried and 1 wet samples will be collected every 30' to TD of well. Samples should be increased to every 10' if lithologies and gas detection warrant. 43 • • �. . .4. . .4. . . . , . . . .4. . . . , . . . .4. . . Ili or )y •• ..v.. 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A. .„,,.. , . , _ ...,. . •lid A qr. • ' 1..4 0..4***0 ire i j :"?.?,,g-sei,- ♦ - t• • f . � ff , '• ' ,/ / .c ,� /�I'.... �0 .S. j dill: ► , /1 //.i j c i i — •4,,,' '1 f o '4., ,/.7 • ,..; 0 .., :O.,.1 ' I.„, , , i (JACK i ._I 44 • • Shallow Hazards Analysis October 9, 2012 Statement to Accompany Permit Shallow Gas potential Olson Prospect Area A thorough review of all wells drilled in the vicinity of the planned well has been conducted with the purpose of identifying any potential shallow gas accumulations which could contribute to well control problems during drilling of the surface hole for the proposed well. No problems Vv were identified with shallow gas as a result of studying the surrounding wells. Additionally, several dip seismic lines and one strike line running nearly through the proposed well have been reviewed for seismic anomalies often associated with shallow gas accumulations. No shallow ,. anomalies are apparent from these lines. The two nearest wells drilled to the planned Olson Creek No. 1 were the Force Energy Coffee Creek#1 and the Phillips North Tyonek State 58838 No. 1 which were drilled Approximately 2.6 miles North and 4.5 miles Southwest respectively. Neither well encountered shallow gas hazards as determined from available well information. The Coffee Creek Well was drilled fault separated across a large South thrusting reverse fault. The well was drilled to a TD of 9757' MD/9664' TVD. First trace amounts of C2 were encountered slightly above 3500' with no significant shallow gas encountered. Conditions similar to this well are anticipated for the proposed shallow section of the new well. Although no shallow gas zones are anticipated to be encountered in the proposed well, a continuous two man mud logging unit will be utilized during drilling operations including d exponent and appropriate care will be exercised while drilling this interval to insure adequate well control should a shallow gas zone be encountered unexpectedly. 16IPagc • • Well Information Casing Tops Plugs Texas International Petroleum 30"@ 41.5' Beluga / 55 Sx from TOF @ 6475-6283 Pretty Creek St#1 20"@ 145.8' Tyonek 60 Sx 6014-5900 API 50-283-20043-00 Permit# 174041 13 3/8"@ 2255.0' Cut&Pull 9 5/8"from 3500' Sec 2 Twn 14N Rge 10 W SM 9 8/8"@ 6429.9' Spot 50 Sx from 3500' Location:678' FEL 324' FSL 21'Cmt Plug in 20" Elev.299' GL TD 6570'MD/TVD *Well Plugged and Abandoned Forcenergy 20"@ 90' RKB Tyonek 700' 7,325'-7,900' Cement Plug 13-3/8"@ 1,219' Three Mile Sand 6,756'-7,133' Cement Plug, Coffee Creek#1 RKB 4,780' EZSV @ 6,800' Chickaloon 5,537'-5,785' Cement Plug, API: 50-283-20094-00 Permit No. 197219 9-5/8"@6,715'RKB 6,630' EZSV @ 5,785' 4,009'-4,415'Cement Plug, Sec 19,T14N,R10W,SM Mesozoic 6,935' EZSV @ 4,100' and 4,415' 2,345'-2,631'Cement Plug, Spud:2/13/98,P&A:6/28/98 liner: 7 5/8"from EZSV @ 2,454' Surface-150',Cement Plug, Elevation 620'MSL 6,638'RKB EZSV @150'. TD:9,757'MD/9,664'TVD to 7,288'RKB *Well Plugged and Abandoned Cities Service 30"@ 60'RKB Beluga 2,805' 10,219'-10,319'Cement Plug Lewis River B-01 20"@ 371'RKB Tyonek 6,550' 9,850'-9,950'Cement Plug API: 50-283-20052-00,Permit No. 13-3/8"@ 2,399' Middle Groung 176031 RKB Shoals 8,312' 8,550'-8,650'Cement Plug 6,658'-6,710'Cement Plug,6,710'- Sec. 10,T14N,R9W,SM 9-5/8"@ 8,557'RKB BP,6,656'-EZSV 2,720',3,764'4,480',6,520'- Location: 300'FNL, 1500'FEL BP's,3,690'-EZSV Elevation:79' KB 2,500'-2,650'Cement Plug TD: 10,319' TVD/MD Suface-100'Cement Plug. *Well Plugged and Abandoned 17 age • • Chevron 20"@ 144'RKB Sterling 1,960' 4,036'-4,587' Cement Plug, 13-3/8"@ 1,920' Pretty Creek Unit 224-28 RKB Beluga 3,870' 4,088' Cement Retainer API: 50-283-20081-00,Permit No. 186076 9-5/8"@ 4,849' 4,272',4,587'EZSV Sec.28,T14N,R9W,SM 1,819'-1,925'Cement Plug Location:762' FNL,2058'FEL 168'BP Elevation: 112' KB Surface-168'Cement Plug TD: 5,182'MD/5,010'TVD *Well Plugged and Abandoned Shallow Hazard:Due to aggressive directional drilling in shallow section hole was becoming under gauged,causing high torque in drill string. Cook Inlet Sand Phillips Petroleum 13-3/8"@ 322'MD 1,684' 4,831'-4,964'Cement Plug N Tyonek State 58838#1 9-5/8"@ 1,321'MD Beluga 2,527' 3,931'-4,064'Cement Plug API:50-283-20040-00,Permit No. 173016 7"@ 6,037' MD 3,724'-3,991'Cement Plug Sec.25,T13N,R11 W,SM 3,079'-3,230'Cement Plug Location:695' FWL, 1679'FSL 2,702'-3,126'Cement Plug Elevation 227' MSL;KB=248.4' 2,135'-2,268'Cement Plug TD:6,063'MD/6,063'TVD 53'-186' Cement Plug *Well Plugged and Abandoned Shallow Hazard:Lost Returns for short time at 1,321'.No signs of down hole problems. Cities Service 30"@ 65' Sterling Surface 11,225'-11,320'Cement Plug East Lewis River#1 20"@ 370' Beluga 4,899' 10,805'-11,225'Cement Plug API:50-283-20048-00,Permit No. 175006 13-3/8"@ 2,375' Tyonek 7,790' 10,678'-10,805'Cement Plug West Foreland Sec. 18,T14N,R8W,SM 9-5/8" 884 11 481' 10 500'-10 678'Cement @ 9 '� e t Plug Location: 1980'FSL, 1,980' FWL liner:7"from 11,225', 10,805' EZSV Retainer Elevation: 15' GR 9,646'to 11,625' 10,678', 10,500',8,012'Retainer TD: 11,636' MD/TVD 6,093'-6,212'Cement Plug 2,205'-2,380'Cement Plug Surface-60'Cement Plug *Well Plugged and Abandoned 181Pa.ge • • Cities Service 30"@ 48' Beluga 2,279' Lewis River 1-A 20"@ 363' Tyonek 5,864' API: 50-283-20047-00,Permit No. 175005 13-3/8"@ 1,368' Bell Island 9,142' Sec.2,T14N,R9W,SM 9-5/8"@ 8,147' Chickaloon 9,414' Location: 1,600' FWL, 1,700' FNL Elevation: 118'KB TD:9,480'TVD Shallow Hazard: 13-3/8"Casing stuck at 1,368'without breaking circulation.Were able to cement pipe. Standard Oil 20"@ 353' 8,820'-9,141'Cement Plug Lewis River 13-2 13-3/8"@ 2,361' 7,754'-7,965'Cement Plug API: 50-583-20011-00,Permit No. 168001 9-5/8"@ 9,088' 7,697'-7,754' Cement Plug Sec.2,T14N,R9W,SM 5,200'-5,303' Cement Plug Location:3,280' FSL,658'FEL Surface-224'Cement Plug Elevation: 135' KB TD: 11,625'MD *Well Plugged and Abandoned Upper Beluga Union Oil 20"@ 75' 2,700' Middle Beluga Lewis River Unit C-01 13-3/8"@ 368' 3,500' API:50-283-20061-00,Permit No. Lower Beluga 178075 9-5/8"@ 2,409' 5,500' Sec.35,T15N,R9W,SM 7"@ 6,569' Location:0'FWL, 1,000'FSL Elevation: 115'KB TD:6,559' TVD/MD Well P&A with 40 bbls of 15.8 ppg cement on top of Retainer set at 2,671' Cities Service 20"@ 359' Beluga 2,096' 7,135'-7,235' Cement Plug Lewis River D-01 13-3/8"@ 2,395' Tyonek 6,210' 6,180'-6,280' Cement Plug API:50-283-20068-00,Permit No. 180141 9-5/8"@ 5,135' 5,875'-5,975'Cement Plug Sec.35,T15N,R9W,SM 5,475'-5,575'Cement Plug Location: 2,086' FWL,3,168'FSL 5,053'-5,135'Cement Plug Elevation: 123'KB 3,792'-3,849'Cement Plug TD: 8,025'MD 3,317'-3,374' Cement Plug 2,745'-2,805' Cement Plug Surface-50' Cement Plug *Well Plugged and Abandoned 191Page • Unocal Oil 13-3/8"@ 120' Beluga 3,648' Pretty Creek Unit 4 9-5/8"@ 2,386' Tyonek 7,070' API: 50-283-20100-00,Permit No. 201193 7"@ 6,942' Sec.33,T14N,R9W,SM Location:3,681'FSL,2,117'FEL Elevation: 100' KB TD:9,580'MD/7,566'TVD Shallow Hazard:Experienced gravel restricting circulation at—2,398'. Halbouty Alaska Oil 20"@ 339' 8,420'-8,675'Cement Plug Theodore River#1 (PCU 2) 13-3/8"@ 2,032' 3,215'-3,450'Cement Plug API: 50-283-20022-00,Permit No. 169015 9-5/8"@ 8,550' Surface—26'Cement Plug Sec.33,T14N,R9W,SM 8,420'Retainer Location: 1,590'FSL,2,140'FWL 7,000'Permanent BP Elevation: 81.9' GR 4,750'Permanent BP TD: 12,025' Shallow Hazard:Did not bring cement to surface,suspected wash out.Had to do top job. 20IPag; • Seismic Information: Confidential 21,110 QS) wi 36 31 32 21163700- 26531.1Ok 26.3700. 12 7 3 2.13700 Cook Inlet Energy CONF IDEN1 AL Project Location:Olson So-ale=1:10000 Issomossaras 0 1500 3000 45001 Olson Well Location&Seismic 2D Base Map 21 ! 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CONFIDENTIAL Project Location: Olson • a�� \/ Line UD-2,Migration 23 Page ! ." Pretty Creek #1 Sec 2 TI4N RIOW Cook Inlet 0 I • I I 1 III I' 1 1 1 • I , • 1000 t �! �. • 2000 - I 1 i 1 i ' 1 • • • I - ' ._J ,i' - —1—— _-.. ——I _—-.4 _ - • • • , ,.. 3000 ; ! i .. ' . ++ I : 44.. 1 I 1 r 1 i 4-1 1 I r 1 i 1 1 CL Q 4000 -, ; ; i� t I 5000 • -- I �1 7)t _ ' I 1 I 1 _ .... . i • I t I I r' 1._ .� ... ` 1 1 I 1 6000 -,-- i " I • 1 F. ; I 1 1 1 e •• 7000 : 4. . I 10.00 100.00 1000.00 Sonic Log Travel Time (Ns/ft) 24IPage • I BOP & Diverter Sketch Operator: Cook Inlet Energy Date 5-Sep-12 amitim .*;�S:isi�S:.,:k. i�i�i�i i,•,... �i- _i�i�i iii:,:, i�i�i�i�i�Skid,41,:�S�i i�. i 24 1,. I I i 28'6"] Bell Nipple Hsdrll"MSP" V I 16"Diverter Line with Hydraulic MIIIIIIIIIIP Actuated Full Opening Valve liMiilNINIZMIIMIN iNEREEMEMON I 1:1 111111. T 0 _G grN w 20" H 26"Hole Section 12 1/4" 45 • • BOPE Schematic Operator: CIE, Patterson ITI'I Rig No.191 Date: 4-Jun-13 IIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIMI I I � Component Height" Annular 49.25 Double U 66.67 Drlg Spool -i1-36" � a tias< Single U41.69" Total: 19341" Cameron D (Top of 13 5/8"5M x 18M USA=GL) Cameron U Cr---"r1/ _ 3 1/2"x 5"VBR 1 3-1/16",IOM,KillLine Blind Rams Fire Rated Hose `--� •`1 a miniMud Cross has 4-1/16",10M Out' 13-5/8"10M it ri, I 4-1116",IOM,KiII Line 11111111 MI Fire Rated Hose II;uI;IISiIiI llI 13.5/$n U 3-1/16",10M Gate Valves Ca U 4.1/16"HCR Gate Valve 3-1/16",10M x 4-1/16",IOMDSA a �—' 4.1/16",10M Gate Valve �--. • 3 112"x 5"VBR 13-5/8"1 1 I 1 5Mx 20M l1 { i, y. L. rltiIl - < 2-1/16",5M,Gate Valve �I. , :.' "1 [ 1Iw. < - 2.1/16",5M,Cate Valve 1. 4 J._ _[ i j i. J-7-, t - t 46 • • 1 ft PATTERSON-UTI TYPE E - 10M Choke Manifold _ Well Control res NM MN NM MO � • • •• 9 •t1k4 WPM• . :• o m . .r ' / ,..1,, CO le-u m o tc��: PR UR PM-334 4 1/16"10M Manual Gate Valves 4 1/16" 10M Manual Choke Valves Valve® thru ® TYPE Cameron, Valve® and » TYPE Cameron. 2 1/16"10M Manual Gate Valve 3 1/16"10M Willis M-3 Remote Choke Valve® TYPE Cameron. Valve® TYPE Cameron. 47 • • Wellhead Schematic (I:6D GE Oil &Gas ar — 02,t, (t.I1' .. . ... 0,....i -. 109 2i11Y* '� ,_. _ ' 2-8110.612 a wE y 11.1• Mr. icor al 1 2Y'tr 112 I : SINIMMI u�. ur Argir mor 112 -. 1.1 �I 1.1 2srn4 19.pIt 6.1 la; ! 11 � 4111{1 110. 1 11.111 • at 2-1nrom '.,' Iit I ii — � "V" 1 - i°is _ F 2.1nr s1 i1 i II 1 • Li ' 1 I j 21.011."...Pt* r oro Ur Career Un.1., TVrConed u. 2-25 Teeing ALL DIMENSIONS ARE APPROXIMATE Tr..cawing.the property or OE w a Oa Promos Conry IP end re oawe.w oarO.rel.Mem a..i.epprc.ed In wary COOK INLET ENERGY,LLC rrw1w rc non de 1or9.rr.may W toed,coped,bsn.aa.d 11 reproduced except as the sole promo(JOE w a o..PM....Cara LP OLSEN#2 9-5/8"x 7"x 2-7/8"5M SH2 Conventional Wellhead Assembly, °FtAWN CR 09JUL14 APPRV KN With T-M40-CCL Tubing Hanger and Adapter Flange FOR REFERENCE ONLY With DRAWING NO. 1001348 48 • ! GeoMechanical Plot- Olson Proposed Geo Mechanical Plot Equivalent Mud Weight(PPG) 8 10 12 14 16 18 20 0 I 2000 Sferli g+�X156 1 13 3/8' Be uga+/-2,0 4 TVD 410 MD 9 5/8" Calc Pore Pressure 4000 M its —Mud o Weight o (Pore 6000 — Tyonek+/-'6,325'ND 7,778'MD Press.+ li 7" Drilling rm�in) Gradient 8000 _ I 5" 10000 — Bottom Hole Pressure Calculation: 10.2*10,024*.052=5316 PSI 49 • • Casing Program Cook Inlet Energy Casing Plan WELL NAME: _ Olson Creek 2 Well Information ENGINEER: Courtney Rust DATE: 17-Jun-14 Max EMW Estimated Hole Sizes Casing Size Estimated Range-Mud MD(ft) TVD(ft) (Pore Frac Grad at Mud Type Comments (in) (in) Weight ht(ppg) r Pressure) Shoe 13 3/8" -- -- — — — Conductor pipe 12 1/4" 95/8" 2,000 1,781 8.9 15.2 8.8 9.2 WBM Norm grad Based on offests 8 1/2" 7" 7,500 6,089 9.8 15.8 8.8 9.8 WBM 6 1/8" 5" 11,967 10,024 10.2 15.8 8.8 10.5 WBM Casing Plan 'ENTER YELLOW CELLS MANUALLY Connection API rating Casing Size Wt(Ib/ft) Grade Collapse Tension MD(ft) TVD(ft) (in) Type OD(in) Burst(psi) (Psi) (kips) 13 3/8" 68 L80 BTC — — — — 0 0 9 5/8" 40 L80 BTC 10.625 6870 5750 1161 2000 1781 7" 26 L80 BTC 7.875 7240 5410 641 7500 6089 5" 18 L80 BTC 10140 10500 457 11967 10024 Variables&Formulas Wellhead 5,000 psi Gas Gradient 0.10 psi/ft Pore Pressure Gradient 0.460 psi MAWP=(0.80 X CASING BURST)or Limiting Wellhead Pressure MASP=Lessor of(Frac Pressure @(0.052 X(MW+0.5ppg SF)X ND)-GasGRD X ND))or(Max Pore Pressure-(GasGRD X TVD)) MASCP=(0.80 X CASING BURST)-(MW-Backup FluidWt.)X.052 X TVD SF Burst=Burst Value/MASP SF Collapse=Collapse Value/((0.052 X Max EMWPore Pressure X TVD)-(gas gradient X TVD)) SF Tension=Tension Value/(Length X lb/ft) 50 • • Max Allowable Working Pressure MAWP=(0.80 XCASING BURST)or Limiting Wellhead Pressure Hole Sizes Casing Size Safety Wellhead MD(ft) TVD(ft) Burst(psi) MAWP(psi) (in) (in) Factor (psi) 12 1/4" 9 5/8" 2,000 1,781 6870 0.8 5,000 5496 8 1/2" 7" 7,500 6,089 7240 0.8 5,000 5792 6 1/8" 5" 11,967 10,024 10140 0.8 5,000 8112 Max Anticipated Surface Pressure MASP=Lessor of(Frac Pressure 9(0.052 X(MW+0.5ppg)X TVD)-GasGRD X TVD))or(Max Pore Pressure-(GasGRD X ND)) Frac Hole Sizes Casing Size Max EM W Frac Grad at MW Safety Gas Max PP at MD(ft) ND(ft) Pressure at MASP (in) (in) (ppg) Shoe Factor Gradient Next TVD (psi) Shoe 121/4" 9 5/8" 2,000 1,781 8.9 15.2 0.50 0.10 1276 2,209 1,276 8 1/2" 7" 7,500 6,089 9.8 15.8 0.50 0.10 4552 4,106 4,106 61/8" 5" 11,967 10,024 10.2 15.8 0.50 0.10 7494 4,314 4,314 Max Allowable Surface Casing Pressure MASCP=(0.80 X CASING BURST)-(MW-Pore Pressure)X.052 X ND Hole Sizes Casing Size Safety Max EM W MD(ft) ND(ft) Burst(psi) MW (Pore MASCP(psi) (in) (in) Factor Pressure) - 12 1/4" 9 5/8" 2,000 1,781 6870 0.8 9.2 8.9 5468 8 1/2" 7" 7,500 6,089 7240 0.8 9.8 9.8 5792 6 1/8" 5" 11,967 10,024 10140 0.8 10.5 10.2 7956 Safety Factors Hole Sizes Casing Size Collapse Tension Liner Length SAFETY FACTORS MD(ft) ND(ft) Burst(psi) Wt(lb/ft) (in) (in) (psi) (kips) (ft) Burst Collapse Tension 12 1/4" 95/8" 2000 1781 6870 5750 1161 40 - 5.4 8.9 14.5 8 1/2" 7" 7500 6089 7240 5410 641 26 - 1.8 2.2 3.3 6 1/8" 5" 11967 10024 10140 10500 457 18 4767 2.4 2.4 5.3 SF Burst=Burst Value/MASP SF Collapse=Collapse Value/((0.052 X Max EMWPore Pressure X ND)-(gas gradient X ND)) SF Tension=Tension Value/(Length X lb/ft) 51 • • Drilling Fluid Program Mi SWACO Cook Inlet Energy,LLC Olson Creek#2 Fluids Program Proposal Summary Olson Creek#2 is a deviated grassroots exploration well that will be drilled utilizing Patterson Rig#191 The objective of the Olson Creek#2 is to test the potential of the lower Beluga and the Tyonek gas intervals It is proposed that a M-I GEL Spud Mud system be utilized for the 12.25"surface hole section to 2,000'MD.In order to minimize the need of having large quantities of product on hand and also reduce the amount of cuttings that need to be hauled away,it is suggested that a highly inhibitive KLA-SHIELD system be used to drill the 8.5" intermediate interval to 8,500'MD.The KLA-SHIELD system will be comprised of 3%KCL and sized Calcium Carbonate.The 6.125"production interval will also utilize the KLA-SHIELD system and be drilled down to 11,967'MD. Contingency products will be on hand to cover events such as mud weight increases and to combat any lost circulation problems that may occur Depth Footage Mud Weight Casing Size Hole Size Casing Intervals Depth MD TVD of Hole Mud System (PPMmp Drilled ® NIA i[[ If I+ 200' 200' NIA . NIA r 9.625"OD 12.25" 8.681"ID 0.1458 j 2, 000' 1,781' 1,980' Gel Spud Mud 8.8-9.2 bbisfft .5, - 8 67164' ID 0.0702 8,500' 6,961' 6,500' Kla-Shield 9.0.9.5 bblsNt 6.125"125' - 0364 ••f 11,967' 10,024' Kla-Shield 9.5.10.5 4.276"ID bbleft ,, 52 • 12.25"INTERVAL SUMMARY Drilling Fluid M-1 GEL Spud Mud System Key Products M-I GEL,GELEX Bentonite Extender,POLYPAC SUPREME UL&Soda Ash Solids Control Shakers,Centrifuge Potential Problems Hole Stability Shallow Gas Washout Swelling Clays INTERVAL MUD PROPERTIES Depth MDlft) Mud Wt Funnel Viscosity Plastic Viscosity Yield Point(lbflOOft API Fluid Loss LGSI%I (PPO) tl Imlf3Omin) 0-2.000 8.8-9 2 85-125 20-40 25-45 <9 <13% NOTE:This program is provided as a guide only. Well conditions will always dictate fluid properties and product additions required for well-bore integrity. Surface Interval Overview Lithology through this zone is a composite of sand and small pea gravel in the upper intervals with a grading downward to predominately sand and some siltstone in the lower zones of this interval. Based upon work done on previous wells in this area,an M-I GEL Spud Mud is recommended for the surface interval. Table 4.1:Initial Fluid Makeup for M-1 GEL Spud Mud(use fresh water) PRODUCT CONCENTRATION M-I GEL 25-27 lb/bbl Soda Ash 0.25-0.5 lb/bbl or as needed GELEX As needed Ido not add until drilling out conductor) Table 4.2:M-I GEL Spud Mud Additions PRODUCT CONCENTRATION M-1 GEL 25.27 lb/bbl Soda Ash 0,25-0.5 lb/bbl or as needed Caustic Soda As needed for a pH of 9.0-9.5 GELEX As needed for viscosity POLYPAC SUPREME UL 0.25 lbs/bbl or as needed to control fluid loss 53 • • 6.125"Interval Summary PRODUCTION INTERVAL Drilling Fluid System KLA-SHIELD Key Products POLYPAC SUPREME UL,DUO-VIS,KCL,KLA-STOP,Busan 1060,DEFOAM-X,ASPHASOL SUPREME,LOTORQ,DRILLZONE,SAFE CARB-20,SAFE CARB-40,M-I WATE,SACK BLACK,CONQOR 404WH&RESINEX Solids Control Shakers&Centrifuge Potential Problems Hole cleaning Loss circulation/Differential sticking Hole stability Running coals INTERVAL MUD PROPERTIES Depth MD(tt) Mud Wt. PV Yield Point HTHP Fluid Loss Cl- LGS (ppg) (lb1100ft2) (lb1100ft2) (mll3Omin) (mgll) (%) 8,500-11,967 9.5-10.5 10-20 15-25 <8 14,000-18,000 <6% NOTE:This program is provided as a guide only.Well conditions will always dictate fluid properties and product additions required for well-bore integrity. Production Interval Overview The production interval will be drilled to a depth of 11,967'MD using a 6.125"bit with the highly inhibitive KLA- SHIELD system at 10.5ppg containing 3%KCL.Wellbore stability is crucial to the interval as several coal seams will be drilled,A well maintained mud system supplemented with good solids control equipment for maximum solids removal will minimize fluid invasion.Proper drilling practices and properly engineered fluid will minimize wellbore instability. Any new fluid that is required should be built to the below specs. KLA-SHIELD Drilling Fluid Formulation: Fresh Water 0.88 bbls DUO-VIS 1.0 ppb(as needed for Rheology) POLYPAC SUPREME UL 1.5—3.0 ppb 3%KCI 10.7 ppb(in base brine) M-I WATE As needed for density KLA-STOP 8.0-12 ppb/2.0—3.0%v/v DRILZONE 0%-2.0%As needed Busan 1060 0.49 ppb 54 I 410 Logging Plan Wireline logging will be LWD Triple combo with the possibility of running the sonic tool. Mud Logging Plan Mud loggers will catch 30' ditch samples and maintain a wet and dry cut. Samples to be sent to state as required by regulations. Mud logging to commence in 8 ''/z"hole immediately below the 9 5/8"casing shoe at 2000'. Solids Control and Equipment Item Equipment Specifications Shakers Brandt King Cobra Triple Shaker Desander 3 cone desander Desilter 24 cone desilter Centrifuge TBA Drilling Waste Storage Drilling wastes will be either granular solids (cuttings), or liquids (drilling mud or water). Cuttings and fluids will be stored in a permitted disposal pool and transferred to super sacks for disposal at the West MacArthur grind and inject facility. 55 • • Cementing Program Cementing Summary: Our cement plan is 100% excess on surface pipe with the use of an inner string cementing method to ensure cement to surface. We assume freshwater aquifers are covered in our operating area. For subsequent casing sections, we look for a sufficient shoe to drill to the section,to cover any perspective zone and isolate them for protection, and to meet the AOGCC regulation of 500' above the highest known hydrocarbon. 56 I • Operator Name: COOK INLET ENERGY LLC 1 i1 Well Name: OLSON CREEK#2 BAKER Job Description: 9-5/8"Surface HUGHES Date: July 23,2014 i7 Proposal No: 1001169299E JOB AT A GLANCE Depth(TVD) 1,781 ft Depth(MD) 2,000 ft Hole Size 12.25 in Casing Size/Weight 9 5/8in, 47 lbs/ft Pump Via 9 5/8"0.0. (8.681".I.D) 47 Total Mix Water Required 6,474 gals Weighted Spacer SealBond Spacer 40 bbls Density 10.0 ppg Lead Slurry Type I Lead 415 sacks Density 12.5 ppg Yield 2.13 cf/sack Tail Slurry Type I Tail 260 sacks Density 15.2 ppg Yield 1.27 cf/sack Displacement Drilling Mud 143 bbls Page 1 Have more questions? You can find us at: http://www.bakerh ughes.comlproducts-and-serviceslpressure-pumping «58» • ! Operator Name: COOK INLET ENERGY LLC FARM Well Name: OLSON CREEK#2 BAKER Job Description: 9-5/8"Surface HUGHES Date: July 23, 2014 Proposal No: 1001169299F WELL DATA ANNULAR GEOMETRY ANNULAR I.D. DEPTH(ft) (in) MEASURED TRUE VERTICAL 12.415 CASING I 200 200 12.250 HOLE I 2,000 1,781 SUSPENDED PIPES DIAMETER (in) WEIGHT DEPTH(ft) O.D. I I.D. (lbs/ft) MEASURED I TRUE VERTICAL 9.625 8.681 47 2,000 j 1,781 Float/Landing Collar set @ 1,960 ft Mud Density 9.50 ppg Mud Type Water Based Est.Static Temp. 95°F Est.Circ.Temp. 84°F VOLUME CALCULATIONS 200 ft x 0.3354 cf/ft with 0% excess = 67.1 cf 1,300 ft x 0.3132 cf/ft with 100% excess = 814.3 cf 500 ft x 0.3132 cf/ft with 100% excess = 313.2 cf 40 ft x 0.4110 cf/ft with 0% excess = 16.4 cf(inside pipe) TOTAL SLURRY VOLUME = 1211.0 cf = 216 bbls Page 2 Have more questions? You can find us at: http://www.bakerhughes.com/products-and-services/pressure-pumping «58» • • Operator Name: COOK INLET ENERGY LLC rein Well Name: OLSON CREEK#2 BAKER Job Description: 9-5/8"Surface HUGHES Date: July 23. 0 2 14 Proposal No: 1001169299F FLUID SPECIFICATIONS Weighted Spacer 40.0 bbls SealBond Spacer+82 lbs/bbl Barite-Sacked @ 10 PP9 VOLUME VOLUME FLUID CU-FT FACTOR AMOUNT AND TYPE OF CEMENT Lead Slurry 881 / 2.13 =415 sacks Type I Cement+0.05%bwoc Static Free+2%bwoc Calcium Chloride+0.4%bwoc CD-32+0.3%bwoc FL-52+ 1 gals/100 sack FP- 6L+2%bwoc Sodium Metasilicate+106.6% Fresh Water Tail Slurry 330 I 1.27 =260 sacks Type I Cement+0.05%bwoc Static Free+2%bwoc Calcium Chloride+0.5%bwoc CD-32+0.1%bwoc FL-52+ 1 gals/100 sack FP- 6L+50.7%Fresh Water Displacement 143.5 bbls Drilling Mud CEMENT PROPERTIES SLURRY SLURRY NO.1 NO.2 Slurry Weight (ppg) 12.50 15.20 Slurry Yield (cf/sack) 2.13 1.27 Amount of Mix Water (gps) 12.02 5.72 Amount of Mix Fluid (gps) 12,03 5.73 Cement is subject to change based on testing or new well information. TO BE PROVIDED BY OPERATOR: Flush is to be provided by operator. Page 3 Have more questions? You can find us at: h ttp://www.ba k e rh u g h e s.co m/products-and-services/pressure-pumping «58» • Operator Name: COOK INLET ENERGY LLC Y 11 Well Name: OLSON CREEK#2 BAKER Job Description: 7"Intermediate HUGHES Date: July 23,2014 Proposal No: 1001169299F- JOB AT A GLANCE Depth(TVD) 6,961 ft Depth(MD) 8,500 ft Hole Size 8.5 in Casing Size/Weight lin, 29 lbs/ft Pump Via 7"O.D. (6.184".I.D) 29 Total Mix Water Required 833 gals Weighted Spacer Seal Bond 40 bbls Density 10.5 ppg Cement Slurry Class G 169 sacks Density 15.8 ppg Yield 1.15 cf/sack Displacement Drilling Mud 313 bbls Page 6 Have more questions? You can find us at: http://www.ba kerh ughes.com/products-and-services/pressure-pumping «58» • • Operator Name: COOK INLET ENERGY LLC Fan Well Name: OLSON CREEK#2 BAKER Job Description: 7"Intermediate HUGHES Date: July 23. 2014 Proposal No: 1001169299F WELL DATA ANNULAR GEOMETRY ANNULAR I.D. DEPTH(ft) (in) MEASURED I TRUE VERTICAL 8.681 CASING I 2,000 I 1,781 8.500 HOLE I 8,500 I 6,961 SUSPENDED PIPES DIAMETER (in) WEIGHT DEPTH(ft) O.D. I I.D. (lbs/ft) MEASURED I TRUE VERTICAL 7.000 ( 6.184 I 29 8,500 6,961 Float/Landing Collar set @ 8,420 ft Mud Density 9.50 ppg Est.Static Temp. 126°F Est.Circ.Temp. 107 °F VOLUME CALCULATIONS 1,000 ft x 0.1268 cf/ft with 40% excess = 177.5 cf 80 ft x 0.2086 cf/ft with 0% excess = 16.7 cf(inside pipe) TOTAL SLURRY VOLUME = 194.2 cf 35 bbls a3 ae'4 4. Page 7 Have more questions? You can find us at: http:l/www.bakerhughes.comlproducts-and-serviceslpressure-pumping «58» • Operator Name: COOK INLET ENERGY LLC Well Name: OLSON CREEK#2 BAKER Job Description: 7" Intermediate HUGHES Date: July 23, 2014 Proposal No: 1001169299F FLUID SPECIFICATIONS Weighted Spacer 40.0 bbls Seal Bond+ 110 lbs/bbl Barite-Sacked @ 10.5 ppg VOLUME VOLUME FLUID CU-FT FACTOR AMOUNT AND TYPE OF CEMENT Cement Slurry 194 I 1.15 = 169 sacks Class G Cement+0.005 lbs/sack Static Free+0.2%bwoc R-3+0.3%bwoc CD-32+0.5% bwoc FL-62+ 1 gals/100 sack FP-6L+43.7% Fresh Water Displacement 312.8 bbls Drilling Mud CEMENT PROPERTIES SLURRY NO.1 Slurry Weight (ppg) 15.80 Slurry Yield (cf/sack) 1.15 Amount of Mix Water (gps) 4.93 Amount of Mix Fluid (gps) 4.94 Cement is subject to change based on testing or new well information. TO BE PROVIDED BY OPERATOR: Flush is to be provided by operator. Page 8 Have more questions? You can find us at: http:/lwww.ba kerhughes.com/products-and-serviceslpressure-pumping «58» • Operator Name: COOK INLET ENERGY LLC Well Name: OLSON CREEK#2 BAKER Job Description: 5"Liner HUGHES Date: July 23,2014 Proposal No: 1001169299F JOB AT A GLANCE Depth(TVD) 10,024 ft Depth(MD) 11,967 ft Hole Size 6.125 in Liner Size/Weight 5in, 18 lbs/ft Pump Via Casing 4 1/2"O.D. (3.826".I.D) 15.1 Casing 5"O.D. (4.276".I.D) 18 Total Mix Water Required 1,849 gals Weighted Spacer SealBond 40 bbls Density 11.0 ppg Cement Slurry Class G 376 sacks Density 15.8 ppg Yield 1.15 cf/sack Displacement Displacement Fluid 186 bbls Page 11 Have more questions? You can find us at: http://www.ba ke rhug hes.com/products•and-services/pressure-pumping «58» • • Operator Name: COOK INLET ENERGY LLC Viii Well Name: OLSON CREEK#2 BAKER Job Description: 5"Liner HUGHES Date: July 23,2014 Proposal No: 1001169299E WELL DATA ANNULAR GEOMETRY ANNULAR I.D. DEPTH(ft) (in) MEASURED TRUE VERTICAL 6.184 CASING I 8,500 I 6,961 6.125 HOLE I 11,967 I 10,024 SUSPENDED PIPES DIAMETER (in) WEIGHT DEPTH(ft) O.D. ( I.D. (lbs/ft) MEASURED TRUE VERTICAL 5.000 I 4.276 I 18 I 11,967 10,024 Drill Pipe 4.5(in)OD, 3.826(in) 7,200 ft ID, 15.1 (lbs/ft)set @ Liner 5.0(in)OD, 4.276(in)ID, 18 11,967 ft (lbs/ft)set @ Depth to Top of Liner 7,200 ft Float/Landing Collar set @ 11,887 ft Mud Density 10.50 ppg Est.Static Temp. 149 °F Est.Circ.Temp. 138 ° F VOLUME CALCULATIONS 1,30011 x 0.0722 cf/ft with 0% excess = 94 cf 3,46711 x 0.0683 cf/ft with 40% excess = 331 cf 80 ft x 0.0997 cf/ft with 0% excess = 8 cf(inside pipe) TOTAL SLURRY VOLUME = 433 cf 77 bbis Page 12 Have more questions? You can find us at: http:/(www.bake rh ug hes.com/prod uctsand-services/pressure-pumping «58» • Operator Name: COOK INLET ENERGY LLC r'.■ Well Name: OLSON CREEK#2 BAKER Job Description: 5"Liner HUGHES Date: July 23,2014 Proposal No: 1001169299F FLUID SPECIFICATIONS Weighted Spacer 40.0 bbls SealBond+ 138 lbs/bbl Barite-Sacked @ 11 ppg VOLUME VOLUME FLUID CU-FT FACTOR AMOUNT AND TYPE OF CEMENT Cement Slurry 433 I 1.15 = 376 sacks Class G Cement+0.005 lbs/sack Static Free+0.4%bwoc R-3+0.3%bwoc CD-32+0.5% bwoc FL-62+ 1 gals/100 sack FP-6L+43.6% Fresh Water Displacement 185.6 bbls Displacement Fluid CEMENT PROPERTIES SLURRY NO.1 Slurry Weight (ppg) 15.80 Slurry Yield (cf/sack) 1.15 Amount of Mix Water (gps) 4.92 Amount of Mix Fluid (gps) 4.93 Cement is subject to change based on testing or new well information. 0.2%BWOC R-3 WILL BE PREHYDRATED(SAME SLURRY AS INTERMEDIATE WITH MORE RETARDER). TO BE PROVIDED BY OPERATOR: Flush is to be provided by operator. Page 13 Have more questions? You can find us at: http:/lwww.bakerh ughes.com/products-and-serviceslpressu re-pumping «58» • HALLIBURTON ,.. 12-114" (311 mm) FX56M PRODUCT SPECIFICATIONS Cutter Type X3-Extreme Drilling IADC Code M222 BodyType MATRIX Total Cutter Count 46 the . CutterDistribution Olga ] r t i.2olw Face 0 0 30 I "4":r Gauge 5 5 1 { w r Up Drill 5 0 0 j Number of Large Nozzles 5 • Number of Medium Nozzles 0 `s A' Number of Small Nozzles 0 Number cf Micro Nozzles 0 Number of Ports(Size) 0 le Number oReplaceable Potts(Size) 0 Junk Slot Area(sg in) 28.02 l NormalizedFace Volume 5121% API Connection 6-5/8 REG PIN Recommended Make-Up Torque* 37,119—43,525 Ftlbs. :AY N aminal Dimensions** �'+ Make-Up Face to N ose 14.92 in-379 mat Gauge Length 4 in-102 nun Sleeve Length 0 in-0 mm 16. Shark Diameter 8.75 in-222 mm Break Out Plate(Mat#fLegacy#) 181955/44050 Approximate Shipping Weight 420Lbs.-191Kg. SPECIAL FEATURES Impact Arrests,1/32"Relieved G age,Up-Drill Cutters on G age Pads,H ex agonTSP Gage Material#663911 *Bit specific recommended make-up torque is a function of the bit I.D.and actuilbit sub O.D.utilized as specified in API RP7G S ection A.8.2. **Design dimensions are nominal and may vary slightly on manufactured product.HalluburtonDrill Bits and S ervices models an continuously reviewed ani refired. Product specifications may change without notice. ®2013 Hallibuton All rights reserved.Sales of Halliburton products end services will be in accord solely withthe terms and conditions contained in the cordract betweenHalliburton and the customer that is applicable to the sale. www.haliburton.com 57 • HALLIBURTON ,. 8-1/2" (216mm) FX74D PRODUCT SPECIFICATIONS Cutter Type X3-Extreme Drilling e1. a IADC Code M434 BodyType MATRIX ' Total Cutter Count 93 a yt; Cutter Distribution 1.223lla 1 r� Face 67 Gauge 19 `• Up Drill 7 Number of Large Nozzles 0 Number of Medium Nozzles 0 Number of Small Nozzles 6 Number of Micro Nozzles 0 4 a *► Number of Ports(Size) 0 Number of Replaceable Ports(Size) 0 Junk Slot Area(sq in) 12.68 NonnalizedFace V olttme 39.67% API Connection 41/2 REG.PIN '* Recommended Make-Up Torque* 12,461—17,766 Ft*lbs. �Ai„ , aa Nominal Dimensions** .; a`r+ Make-Up Face to N ose 12.98 in-330 nam Gauge Length 4 in-102 mm Sleeve Length 0 in-0 mm Shank Diameter 6 in-152 mm Break Out Plate(Mat#/Legacyit) 181954/44040 Approximate Shipping Weight 170Lbs.-77Kg SPECIAL FEATURES Up-Drill Cutters on Gage Pads,Hex agon TSP Gage,Optimized Dual Row-"D"Feature Material#661050 *Bit specific*commended make-up brgue is a frnction of the bit I.D.ant acbalbit sub O.D.utilized as specified in API RP7G SectionA.8.2. **Design dimensions are nominal and may vary slightly on manufactured product.Hallrburton Drill Bits and S ervices models are continuously reviewed and refired. Product specifications may change without notice. Cs 2012 Hallibuton All rights reserved.Sales of Halliburton products and services will be in accord solely with the terms and conditions contained in the cork act betw a en H alliburton and the customer that is applicable to the sale. www.halliburton.com 58 S • HALLU®URTON ,, __, 6-1/8" (156mm) MM64D PRODUCT SPECIFICATIONS Cutter Type SelecCutter Ilk .1 IADC Code M434 se le t I•.,' 13odyType MATRIX 14' .c: Total Cutter Count 55 ! • r Cutter Distribution 123E 1 s811 .l y„•: / Face 12 25 ', \,( N. G auge 0 12 ' Up Drill 0 6 9. eat N. Number of Large Nozzles 0 Number of Medium Nozzles 0 Number of Small Nozzles 0 Number of Micro Nozzles 6 l Number of Potts(Size) 0trt r4 Number of Replaceable Ports(Size) 0 (.1:*:::' `� �` Junk Slot Area(sq in) 537 NormehzedFace V dome 2599% *t API Connection 3-1/2 REG.PIN 01:� i Recommended Make-Up Torque* 5,173—7,665 Ft*lbs. •:•j N arninal Dimensions** Make-Up Face to Nose 9.35 in-237 mm - G auge Length 2 in-51 mm Sleeve Length 0 in-0 mm f Shank Diameter 4.5 in-114 mm Break Out Plate(Matt/ILegacy#) 181953/44030 Approximate Shipping Weight 90Lbs.-41Kg .a SPECIAL FEATURES Up-Drill Cutters onGage Pads,1/32"RelievedG ege,Optimized Dual Row-eD°Feature Material#780706 *Bit specific:commended make-up torque is a function of the bit I .and actual bit sub O.D,utilized as specified in API RP7G S ection A 8.2. **Design dimensions are nominal and may vary slightly on manufactured peodsct Halliburton Drill Bib and S ervices models an continuously reviewed and refired. Adduct specifications may change without notice. ©2013 H alliburton All rights reserved.Sales of Halliburton products and services will be in accord solely with the terms and conditions contained in the cortract betweenH alliburton and the custom er that is applicable to the sale. www.hafHburton.com 59 • . Regulatory Waiver and Special Procedures Requests AOGCC Regulation 20 AAC 25.235 Gas Disposition /sal Ga. t-2 CIE requests permission to vent or flare gas from the WMRU=0$ well test for a period of 14 days according to 20 AAC 25.235 d(6). Maximum anticipated daily flaring is expected to be 1MMSCF/D with a total expected not to exceed 10 MMSCF over the entire test. If-the well is, successful,-itt w-iillbe tied into the-West McArthur-production facility. AOGCC Regulation 20 AAC 25.265 Automatic shut-in equipment a well that is capable of unassisted flow of hydrocarbons to surface and that has an onshore surface location that is 660 feet or less of (A) a permanent dwelling intended for human occupancy,including a billeting camp or private residence; (B) an occupied commercial building, excluding a structure located within an existing oil or gas field; (C) a road accessible to the public; (D) an operating railway; (E) a government maintained airport runway; (F) a coast line measured at mean high water; (G) a public recreational facility; or (H) navigable waters as defined by the United States Army Corps of Engineers in 33 C.F.R. Part 329.4 with boundaries defined in 33 C.F.R. 329.11; The Olson#2 exploration well is located on a logging type road which is not considered as public access. Cook Inlet Energy does not intend to install a SSSV should the well be completed and requests confirmation from the AOGCC that it would also not consider the well road as a public access way. tz;U ��i C/ -!`G a- �'-c" 1.1"y . ,..z„, 60 • A 2.3-005787-0 C C A s Recording District 301 Anchorage A 01/31/2013 02:40 PM Page 1 of 5 111111111111111111111111$11111111111111111111 11111 RECORDING COVER SHEET Record this document in the Anchorage Recording District Index this document as follows: Title: Addendum No. 3 to Competitive Oil and Gas Lease MHT 9300063 Grantors: State of Alaska, Department of Natural Resources, Mental Health Trust Land Office Grantee: Cook Inlet Energy, LLC Original Lease Recorded: 2006-070606-0, Anchorage District Legal Description: T. 13 N, R. 11 W, SEWARD MERIDIAN, ALASKA TRACT A: SECTION 1: SURVEYED, W1/2NW1/4(80.00 ACRES) SECTION 2: SURVEYED,ALL (640.00 ACRES) SECTION 3: SURVEYED, ALL, EXCLUDING THE BELUGA RIVER (605.00 ACRES) SECTION 10: SURVEYED, ALL, EXCLUDING THE BELUGA RIVER (580.00 ACRES) SECTION 11: SURVEYED, ALL (640.00 ACRES) • • SECTION 13: UNSURVEYED, 5E1/4, EXCLUDING THE BELUGA RIVER (139.00 ACRES) SECTION 14: SURVEYED, ALL, EXCLUDING THE BELUGA RIVER (587.00 ACRES) SECTION 15: SURVEYED, ALL, EXCLUDING THE BELUGA RIVER (635.00 ACRES) THIS TRACT CONTAINS 3,906.00 ACRES, MORE OR LESS. TRACT B: SECTION 1: UNSURVEYED, E1/2NW1/4, 51/2 (560.00 ACRES) SECTION 12: UNSURVEYED, ALL (640.00 ACRES) SECTION 13: UNSURVEYED, N1/2, SW1/4, EXCLUDING THE BELUGA RIVER (460.00 ACRES) THIS TRACT CONTAINS 1,660.00 ACRES, MORE OR LESS. AGGREGATING 5,566 ACRES, MORE OR LESS. After recording, please return to: Cook Inlet Energy, LLC 601 W. 5th Avenue, Suite 310 Anchorage, AK 99501 111E111111111111111111 111111 I! Page 2 of 5 2013-005787-0 • • Addendum No. 3 to Oil and Gas Lease MHT 9300063 This Addendum is entered into by the State of Alaska, Department of Natural Resources, Mental Health Trust Land Office("TLO"or"Lessor") and Cook Inlet Energy, LLC (Lessee). The purpose of this Addendum is to modify the above referenced lease as follows: 1. Change in Legal Description: The legal description of the Leased Area is modified to add approximately 1660 acres. This additional acreage is described as follows: Unsurveyed sections with Tract B: Section 1: E l/2NW 1/4,NE1/4, S1/2; Section 12: All; Section 13:N 1/2, SW 1/4 excluding the Beluga River, all in Township 13 North, Range 11 West, S.M., containing 1660 acres,more or less, as depicted on Attachment A to this Addendum. 2. Effective Date of this Addendum: January 1, 2013. All other terms and conditions of Upland Mining Lease MHT 9300063 remain in effect. This Addendum is attached and made a part of MHT 9300063. :*:*****:***********************:******** • MI-IT 9300063 I Addendum No.3 Page l of 2 ' I I D l iII I I l I,)I I I I l I Ii ,. Page 3 of 5 2013-005787-0 0 • IN WITNESS WHEREOF,the parties hereto have executed this Addendum effective as of the date above written. LESSOR: LESSEE: ALASKA MENTA HEALTH COOK I L T ENERGY,LLC TRUST AUTI j-e r' P By its agent:fr //ld Office I By: " ter„ By: vio,l1-ar S. w',\c.. reoe,- . Jones Title: S Exec rtive Director STATE OF ALASKA ) ) ss. Third Judicial District ) 14 This is to certify that on this day of January, 2013, personally appeared Gregory L, Jones, known to me to be the Executive Director of the Mental Health Trust Land Office, and who acknowledged to me that he executed the foregoing instrument, on behalf . ON 44l Health Trust Land Office, as agent for the Alaska Mental Health Trus . r ,tr , . nd voluntaril h and for the urposes therein stated. r • Notary Public for the State f l skaCr'. ;, BLIC! My Commission expires " 0 -�-t C e 4/4.".....ii.-1;1'c9fe STATE 41191/AC `KA ) ) ss. Third Judicial District ) This is to certify that on this a g- day of January, 2013 before me appeared L.v3 A- 3, WI 1 cox, known to me to be the .S`t cJLe.,,4-- of Cook Inlet Energy, LLC, and who acknowledged to me that he/she executed the foregoing instrument, on behalf of said corporation, pursuant to its by-laws or a resolution of its board of directors and for the purposes therein stated. #1._.c� ......�f4..), tar Public fort Sate of A aska , I •, y c/r& F��.c'• Iy Commission expires: it-t1 13 El 1 MHT 9300063PUBLIC 0,,,....:„1 ' Page 2 of 2 No.3 E ._ fir4'. •.�`oo''3-.:',..•,". � II�IIIIII!III'IIIIII� IIIIiI1III(II III I II I1IIII)III I III f��//11iO1f11\1��\1�'��' Page 4 of 5 2013-005787-0 a • . si I, ...-....„....:...:„.,,...„..-...,,,,:cf..7 a r): a " : o "0 N S.w h o t t � ► .k ++ + r• pt • rrl r. • • • 1r +*: ii.�.•++ d+:*••:•.*/ moi+i+iii+i+iQ+i.:. + +% o -0,.+ 1+1►'�'+++•+o+i+.*o++i+i+o+o+i+o+++o+oioo4+..... i...... ir + i+ i • Addendum No. 3 to Oil and Gas Lease MHT 9300062 This Addendum is entered into by the State of Alaska, Department of Natural Resources, Mental Health Trust Land Office ("TLO" or"Lessor") and Cook Inlet Energy (Lessee). The purpose of this Addendum is to modify the above referenced lease as follows: 1. Suspension and Extension of Lease Term: Operations on this Lease are suspended as of October 31, 2013. This Lease is extended for one (1) year from its current expiration date of December 31, 2013, and will now expire at 11:59 P.M. on December 31, 2014 unless extended pursuant to the existing lease terms. The effective rental rate will be $3.00/acre/year. 2. Modification of paragraph: Paragraph 12 is changed to read as follows: 12. Requirement to Drill. In order to secure the lease extension provided for in Addendum No. 3 to this Lease, the drilling requirement for this Lease is modified to require completion of the Olson Creek No. 1 well to a depth adequate to test the Beluga Formation by August 30, 2014. Failure to do so will result in the termination of this Lease or lease MHT 9300063,to be determined at the sole discretion of the Lessor. 3. Effective Date of this Addendum: December 31, 2013. All other terms and conditions of Upland Mining Lease MHT 9300062 remain in effect. This Addendum is attached and made a part of MHT 9300062. ************************************** MHT 9300062 Addendum No.3 Page 1 of 2 i r IN WITNESS WHEREOF,the parties hereto have executed this Addendum effective as of the date written above. LESSOR: LESSEE: ALASKA MENTAL HEALTH COOK INLET ENERGY TRUST AUTHORITY By its agent: Trust Land Office By: By: Marcie Menefee Title: Executive Director STATE OF ALASKA ) ) ss. Third Judicial District ) This is to certify that on this day of January, 2014, personally appeared Marcie Menefee, known to me to be the Executive Director of the Mental Health Trust Land Office, and who acknowledged to me that he executed the foregoing instrument, on behalf of the Mental Health Trust Land Office, as agent for the Alaska Mental Health Trust Authority, freely and voluntarily and for the purposes therein stated. Notary Public for the State of Alaska My Commission expires: STATE OF ALASKA ) ) ss. Third Judicial District ) This is to certify that on this day of January, 2014 before me appeared known to me to be the of , and who acknowledged to me that he/she executed the foregoing instrument, on behalf of said corporation, pursuant to its by-laws or a resolution of its board of directors, and for the purposes therein stated. Notary Public for the State of Alaska My Commission expires: MHT 9300062 Addendum No.3 Page 2 of 2 • Addendum No. 4 to Oil and Gas Lease MHT 9300063 This Addendum is entered into by the State of Alaska, Department of Natural Resources, Mental Health Trust Land Office ("TLO"or"Lessor") and Cook Inlet Energy (Lessee). Theose u of this Addendum is to modifythe above referenced lease as follows: P � 1. Extension of Lease Term: This lease is extended from its current expiration date of December 31, 2013. This lease will now expire at 11:59 P.M. on September 1, 2014 unless extended pursuant to the existing lease terms. The effective rental rate will be $3.00/acre/year. 2. Modification of paragraph: Paragraph 12 is changed to read as follows: 12. Requirement to Drill. In order to secure the lease extension provided for in Addendum No. 4 to this ease, Lessee agrees to spud a well on this lease by September 1, 2014. Lessee commits to the payment of a penalty to Lessor in the amount of$250,000 if a well is not spud on this lease by September 1, 2014. 3. Effective Date of this Addendum: December 31, 2013. All other terms and conditions of Upland Mining Lease MHT 9300063 remain in effect. This Addendum is attached and made a part of MHT 9300063. ******************************************** MHT 9300063 Addendum No.4 Page 1 of 2 • ! IN WITNESS WHEREOF, the parties hereto have executed this Addendum effective as of the date above written. LESSOR: LESSEE: ALASKA MENTAL HEALTH COOK INLET ENERGY TRUST AUTHORITY By its agent: Trust Land Office By: By: Marcie Menefee Title: Executive Director STATE OF ALASKA ) ) ss. Third Judicial District ) This is to certify that on this day of January, 2014, personally appeared Marcie Menefee, known to me to be the Executive Director of the Mental Health Trust Land Office, and who acknowledged to me that he executed the foregoing instrument, on behalf of the Mental Health Trust Land Office, as agent for the Alaska Mental Health Trust Authority, freely and voluntarily and for the purposes therein stated. Notary Public for the State of Alaska My Commission expires: STATE OF ALASKA ) ) ss. Third Judicial District ) This is to certify that on this day of January, 2014 before me appeared known to me to be the of , and who acknowledged to me that he/she executed the foregoing instrument, on behalf of said corporation, pursuant to its by-laws or a resolution of its board of directors, and for the purposes therein stated. Notary Public for the State of Alaska My Commission expires: MHT 9300063 Addendum No.4 Page 2 of 2 RECEIVED STATE OF ALASKA , __\M--. 1, i3KAOILAND GAS CONSERVATION COMMIS* UL. 2 2 2014 PERMIT TO DRILL ��q ?,� 20 AAC 25.005 _ n(' G /r r; rt, �' 1a.Type of Work: 11b.Proposed Well Class: Development-Oil _ Service- Winj — Single Zone/ — 1c.Specify i I p••'•- �I. Drill Lateral _ Stratigraphic Test Development-Gas _ Service-Supply _ Multiple Zone _ Coalbed G Gas Hydrates Redrill Reentry _ Exploratory Service- WAG Service-Disp Geother al R Shale Gas 2.Operator Name: 5. Bond: Blanket Single Well U 11.W rName and Number: COOK INLET ENERGY,LLC Bond No. 1212870 OLaN CREEK WELL#2 3.Address: 6.Proposed Depth: 17.Field/Pool(s): 601 W 5TH AVE SUITE 310,ANCHORAGE,ALASKA 99501 MD: 11967 TVD: 10024/ 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): / EXPLORATORY Surface: 2593'FWL,2931'FNL,Sec 6,T13N,R1OW SM MHT 9300062 Top of Productive Horizon: 8.Land Use Permit: / 13.Approximate Spud Date: MHT 9300062 8/15/14 Total Depth: 9.Acres in Property: / 14.Distance to Nearest Property: 5483 / 2,640'FNL,2,640'FEL / 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MS 318 feet 15.Distance to Nearest Well Open Surface: x- 264980.00 y- 299832 Zone 4 GL Elevation above MS 271/.5 feet to Same Pool: N/A 16.Deviated wells: Kickoff depth:600' feet 17.Maximum Anticipated Pressurpsig(see 20 AAC 25.035) Maximum Hole Angle: 51 degrees Downhole: 4560/ Surface: 4314 PSI 18.Casing Program: Specifications Top - Setting pth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD / MD TVD (including stage data) Driven 13 3/8" 68# L80 B- TC 200' 0 0 ! 200 200 – 12 1/4" 9 5/8" 40# L80 r B- TC 2,000' 0 2,000' 1,781' 142 sxs 8.5" 7" 29# L80 BTC 8,500' 0 0' 8,500' 6,961' 170 sxs 6 1/8" 5" 18# L80 r B- TC r 4,767' 7,200' j 851' 11,967' 10,024' 376 sxs 9. PRESENT WELL CONDITION SUMMARY(To be completed for Re I and Re-Entry Operations) Total Dep 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 . Perforation Depth TVD(ft): 20. Attachments: Property Plat IJ BOP Sketch u Drilling Program Time v.Depth Plot W Shallow Hazard Analysi Diverter Sch k 2 Seabed Report Drilling Fluid Program j 4 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: j Date 22-Jul-14 22. I hereby certify that the foregoing is true and correct. / COURTNEY RUST 433-3809 Contact COURTNEY.RUST @ COOKINLET.NET Email Printed Name CONRAD-ERRY /, Title DRILLING MANAGER i A '; Signature / Phone 907-727-7404 Date 22-Jul-14 / Commission Use Only Permit to Drill API Number Permit Approval See cover letter for other Number: a I 1 - )1 3 0- 8-a 01 Z`I_00- o0 Date: 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: Other: Samples req'd: Yes No _ Mud log req'd:Y Nc__ H2S measures: Yes No_ Directional svy req'd:Y Nc_ • Spacing exception req'd: Ye No Inclination-only svy req'd:Y Nc — APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ORIGINAL Submit Form and Form 10-401(Revised 10/2012) This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Attachments in Duplicate • • Cook Inlet Energy_ RECEIVED JUL 222014 AOGCC July 22, 2014 Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill Cook Inlet Energy, LLC: Olson Creek#2 Dear Ms. Foerster, Cook Inlet Energy (CIE) hereby submits a completed Form 10-401 and Permit to Drill application for the Olson Creek#2 well located on CIE lease#MHT 9300062, Also, attached are proposed wellbore schematics, MASP calculations, Rig Drawing, and a BOP configuration diagram. Patterson Rig - 191 will be used to complete this work, commencing approximately August 1, 2013. Maximum Anticipated Surface Pressure for this well is 4314 PSI. Please note waiver and permission to flare requests are located at the end of this submittal. If you have any questions, please contact me at(907) 727-7404. Sincerely, /?'"t/ Conrad Pe Drilling Manager Cook Inlet Energy 601 W.5th Avenue,Suite 310,Anchorage,AK 99501 (907)334-6745*(907)334-6735 fax STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM AllON PERMIT TO DRILL 20 AAC 25.005 la.Type of Work: 1 b.Proposed Well Class: Development-Oil ❑ Service- Winj ❑ Single Zone ❑ lc.Specify if well is proposed for: Drill ❑✓ Redrill ❑ Stratigraphic Test ❑ Development-Gas❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Re-entry ❑ Exploratory ❑I Service- WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Q Single Well ❑ 11.Well Name and Number: COOK INLET ENERGY,LLC Bond No. 61212870 OLSON CREEK WELL#2 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 601 W 5TH AVE ANCHORAGE,ALASKA 99501 MD: 11,967 TVD: 10,024 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): EXPLORATORY Surface: 2593'FWL,2931'FNL,Sec 6,T13N,R1OW SM MHT 9300062 Top of Productive Horizo 2506.30'FEL,1960.18'FNL,Sec 1,T13N,R11W Sk 8.Land Use Permit: 13.Approximate Spud Date: MHT 9300062 8/1/2014 Total Depth:3510.08'FEL,1794.40'FNL,Sec 1,T13N,R11W SM 9.Acres in Property: 14.Distance to Nearest Property: 5483 2,640'FNL,2,640'FEL 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 318 15.Distance to Nearest Well Open Surface: x-264980 y- 299832 Zone- 4 GL Elevation above MSL: 291.5 to Same Pool: N/A 16.Deviated wells: Kickoff depth: 600 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 51 degrees Downhole: 3559 psi Surface: 4314 psi 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) Driven 13 3/8" 68# L80 BTC 200' 0 0 200 200 -- 12 1/4" 9 5/8" 40# L80 BTC 2,000' 0 0' 2,000' 1,781' 142 sxs 8.5" 7" 29# L80 BTC 8,500' 0 0 8,500' 6,961' 170 sxs 6 1/8" 5" 18# L80 BTC 4,767' 7,200' 5,851' 11,967' 10,024' 376 sxs 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 - • Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production • -r Perforation Depth MD(ft): Perforation Depth ND(ft): 20. Attachments: Property Plat Q BOP Sketch ❑✓ Drilling Program ❑✓ Time v.Depth Plot Q Shallow Hazard Analysis ❑✓ Diverter Sketch ❑✓ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date 12-Jul-14 22. I hereby certify that the foregoing is true and correct. Contact Courtney Rust 433-3809 Printed Name Conrad Perry Title Drilling Manager Signature Phone 907-727-7404 Date 7/12/2014 Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: 50- Date: 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: ❑ Other: Samples req'd: Yes❑ No❑ Mud log req'd: Yes ❑ No ❑ H2S measures: Yes❑ No❑ Directional svy req'd: Yes ❑ No ❑ APPROVED BY THE COMMISSION DATE: ,COMMISSIONER Form 10-401(Revised 7/2009) This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Submit in Duplicate • • RIG#191 SCHEMATIC AND PAD ORIENTATION 1 LOCATION PLAT 2 DRILLING PROCEDURE-OLSON CREEK 2 3 FORMATION INTEGRITY TEST PROCEDURE 7 PROPOSED WELLBORE DIAGRAM 8 OLSON CREEK 2 ANALYSIS 35 GEOMECHANICAL PLOT- 45 LOGGING PLAN 51 MUD LOGGING PLAN 51 SOLIDS CONTROL AND EQUIPMENT 51 DRILLING WASTE STORAGE 51 CEMENTING PROGRAM 52 SURFACE: 52 INTERMEDIATE 53 PRODUCTION 54 BIT PROGRAM 56 REGULATORY WAIVER AND SPECIAL PROCEDURES REQUESTS 59 • • Rig #191 Schematic and Pad Orientation A c' En m o _ I N__ O »9p — r, aw a. <0o, V) 446 c7 D O o J oma i ..i4.1 , I O, m P m '5' 1 FRr It I , , ---,?--.1_.-_,2 :1.. i-- D , (.„, _....._ , _ („iYT, 1— , , -=—_,,,,,Jw T .... , I o „,,, . ,P - _ _ 6m w � _7'-9^ ES g WI: „: .„11,,,,,,, o n 41----p( t— 1-�- ii-„' — I sr,. zil Dw v O A q E 4 r4 _ m-$' �m 6�A r QQ — �go� �: fn z § a54,4� j a I gg N �� p' I $ , $ i li , y' EE 1 1 oqo 5 I f I 4 ,10T; - _ 1 r I Pf Ell gm - - 80'-7” 5?'-5” 0 0v ww U) sO 146'-ll" O r v 'i z Z O Oite I 1 • • Location Plat 2 • • 36 31 ill! ) SECTION LINE NOT TO SCALE 1 6 I FND BLM MON SECTION CORNER N:2651908.705' E:297287.602' �zf •Iel LZ/). SECTION 6 T13N R1OW o0 2735'FNcn 1 O /4� H 4 H 00 AS-STAKED WELL OLSON CREEK NO.2 N:2649125.417' w E:299874.309' J LAT:61° 14'45.698"W z LON: 151°08'10.548" v o NAD27 ASP Z4 PAD EXPANSION 0 ELEV:291.6(NAVD88) / 2629'FWL a- / 0 ' OLSON CREEK NO. 1 LIMITS EXISTING GRAVEL PAD NOTES 1. BASIS OF HORIZONTAL CONTROL:NAD83 US FEET POSITION (EPOCH 2003)AND VERTICAL CONTROL(NAVD88)IS AN OPUS _ ��,xx�Vtl111 SOLUTION FROM NGS STATIONS TSEA,AC51 AND ANC2 TO -_ ��OF q�q Ii ESTABLISH CP-39. THE ALASKA STATE PLANE COORDINATES NAD ::-.. .•'' S,1 II 27 ZONE 4 IN FEET ARE: N=2649260.142 *:/1:4H c .*�, E=299747.051 ii ELEV.=306.233(NAVD88) IIIIIII! 'lllllll1{I i ' //F"` �[� / '. STAN A.McLANE . i 2-SECTION LINES SHOWN ARE PROTRACTED VALUES ADJUSTED / 4637-S TO MATCH FOUND BLM CORNER. SCALE ij Z4TFAA.LYW WERE DONE USING CORPS3. DATUM ONS(NAD83 CON6 SOFTWARE.4 TO NAD27 ASPZ4) 0 I 200 i 400 ,lll1ti.xxxxs�` / Il FEET PROJECT REVISION: 1 COOK INLET ENERGY DATE: 7/24/14 C©©k i i Epi OLSON CREEK NO. 2 DRAWN BY: MSM I y AS-STAKED SURFACE LOCATION SCALE: 1•=200 NAD 27 PROJECT NO. 143092 BOOK NO. 12-17 111. ENGINEERING/MAPPING/SURVEYING/TESTING Consulting Inc P.O.BOX 468 SOLOOTNA.AK.99669 LOCATION SEC. 06 T13N R10W SHEET VOICE;(907)283-4218 FAX:(907)283-3265 EMAIL:SAMCLANE@MG ANE°°.°GM SEWARD MERIDIAN, ALASKA 1 OF 1 • • 36 31 iM ) SECTION LINE NOT TO SCALE 1 6 / FND BLM MON SECTION CORNER N:2651669.042' E:1437316.587' i r SECTION 6 T13N R1OW LU U /U 2735'FN,` U) / LU O 4 F— O p �' AS-STAKED WELL Z OLSON CREEK NO.2 N:2648885.734" z E:1439903.017' _ LAT:61° 14'43.686"W 11, o LON: 151°08'18.568"W 1= NAD83 ASP Z4 PAD EXPANSION; w ELEV:291.6(NAVD88) 2629'FWL �- 0 is 1� OLSON CREEK NO. 1 i� LIMITS EXISTING GRAVEL PAD NOTE 1. BASIS OF HORIZONTAL CONTROL:NAD83 US FEET POSITION - ```��11 (EPOCH 2003)AND VERTICAL CONTROL(NAVD88)IS AN OPUS �% 'P. .'.?(..4�I SOLUTION FROM NGS STATIONS TSEA,AC51 AND ANC2 TO �p�� s�I, ESTABLISH CP-39. THE ALASKA STATE PLANE COORDINATES NADN i* *�•/ 83 ZONE 4 IN FEET ARE: imam `� (� N=2649020.459 a i� E=1439775.772 " �"O' II / STAN A.McLANE ELEV.=306.233(NAVD88) j ass?-s SCALE I - • ...�'-,24tn,u-YNt... 2.SECTION LINES SHOWN ARE PROTRACTED VALUES ADJUSTED 0 200 400 ,��4a.1\\"`,��` IiTO MATCH FOUND BLM CORNER. , FEETI PROJECT REVISION: 1 COOK INLET ENERGY DATE: 7/24/14 CooCnlet Ener _ OLSON CREEK NO. 2 DRAWN BY: MSM AS-STAKED SURFACE LOCATION SCALE 1=200 NAD 83 PROJECT NO 143092 ENGINEERING/MAPPING/SURVEYING/TESTING BOOK NO. 12-17 /,CansuLting Inc P.O.BOX 468 SOLDOTNA,AK.99669 LOCATION SEC. 06 T13N MOW SHEET VOICE:(907)283-4218 FAX:(907)283-3265 EMAIL:SAMCLANE@MCLANECG.COM SEWARD MERIDIAN, ALASKA OF 1 • • Cook Inlet Energy_ Drilling Procedure - Olson Creek 2 Pre-Spud 1. Stake Well Location 2. Drive 20" conductor to refusal at+/- 100'. 3. Install Mouse hole 4. Install 8' Well Cellar 5. Install 20" starting head 6. Clear and prep location Drilling General Note: Full opening Safety Valve will be on rig floor at all times with appropriate crossovers for all pipe being run below rotary table. 1. Move in and Rig Up Patterson 191. 2. Nipple up 21 1/4" diverter and 12 1/4" diverter lines, if required. Function test system prior to AOGCC witness. a. 48 hours' notice for remote operations 3. Pick up and stand back 5" drill pipe. 4. Function test diverter and witness by AOGCC. Give 48 hour notice. 5. Pick up 12 1/4" BHA: a. 12 1/4" MX-1 bit b. 8" Mud Motor with 1.22 bend c. 8" Stabilizer d. MWD w/GR e. 3 Flex Collars f. Weatherford 7-3/4"jars g. 21 Joints HWDP. 6. Clean out conductor and spud well. Note time and date in report. 7. Drill 12 1/4"vertical hole to 500' kick off point, per directional plan. 8. Directionally drill 12 1/4" hole to 2013'MD/1790'TVD. 9. Circulate Hole Clean. Check for Flow. POH. Stand back directional tools. 3 • • a. Note: If any sign of swabbing, run back to bottom immediately. b. Pump/Rotate out of hole if necessary. 10. Rig up to run 9 5/8" casing. 11. Run 9 5/8", 40#, L80 Buttress casing to +/- 2,000' with Float Shoe and Stab-in float Collar on joint up. Land casing elevators on wood blocks close to RT. a. Centralize casing i. One per joint on first 4 joints ii. One per 4 joints to conductor. 12. Make up false rotary and surface flow nipple. 13. Pick up cementing stinger and centralizer. 14. RIH on 5" drill pipe. 15. Stab into float collar. Establish circulation slowly. 16. Rig up cementers and test lines. 17. Pump 12.5 ppg lead cement until returns to surface. Tail with 500' of 13.0 ppg. Plan to use 100% excess, per cement program. Dump excess cement into cellar. Have cement retarder on hand. 18. Un-sting from collar and check for back flow. Drop wiper ball and circulate drill pipe clean. 19. POH with drill pipe. Rig down false rotary. 20. WOC for 12 hours minimum. a. Check for flow on both inside and annulus. b. Lift riser& make rough cut on 9 5/8" casing. c. Lay down casing stub. d. Nipple down diverter. 21. Nipple Down Diverter. Dress conductor and 9 5/8" casing. Check for cement to surface. Perform top job if cement is not at surface. 22. Install, weld, and test Vetco 5M 13 5/8" multi-bowl wellhead. Orient to match existing wellheads on pad. 23. Nipple up and test 13 5/8" BOPE with 3 '/2" x 5" VBR pipe rams, Blinds in middle. a. Test Rams to 3500 psi b. Test Annular Bag to 2500 psi. 24. Clean pits and make up new mud system. 25. Pick up and stand back sufficient 5" drill pipe if not done already. 26. Pick up 8 '/2" BHA: a. 8 '/2" PDC Bit b. 7 5/8" Mud Motor c. MN Stabilizer d. 6 3/4" MWD-GR e. PWD Sub f. NM Stabilizer 4 • • g. 3x63/4"NMDC h. 6 Joints HWDP i. Jars j. 14 Joint HWDP 27. RIH to 1000'. Perform shallow MWD test. 28. Continue RIH. Test Casing to 3000 psi. Drill out float collar, shoe track and float shoe. Drill 20' of new formation. Circulate and condition mud. a. Perform FIT to minimum 12.0 ppg EMW (Take to leak off pressure) 29. Directionally drill 8 '/2"hole to 8,500' MD/6,961' TVD, per directional plan. 30. Circulate hole clean with minimum of three bottoms up. Preferred procedure is first circulation on bottom, pull a stand for the next, and same for the third and fourth if necessary. Pull out of hole. Avoid back reaming if possible. Pump out of hole, if necessary. 31. Lay down all smart iron and expedite back to Halliburton. 32. Make wiper trip if needed. 33. Rig up to run 7" casing. Change upper rams to 7" and test to 3000 psi. 34. Run 7", 26#, L80 BTC to bottom. a. Centralizer program to be as follows: i. 1 Solid body spiral centralizer every joint through planned TOC. ii. 1 Solid body spiral centralizer every 4th joint thereafter. b. Break circulation at 5000' and 9 5/8" shoe, and every 2000' in open hole. c. Note swab and surge pressures of tripping are excessive with 7" casing in 8 '/2" hole at this depth. 35. Circulate and condition hole. Reciprocate casing while circulating. 36. Rig up and test cementers. Cement 7" casing according to program. Continue reciprocating casing while pumping cement. Land Casing and Bump plugs with 3000 psi. Release pressure and check floats. a. Ensure cement is a minimum of 1000' above top of highest known hydrocarbons. 37. Set and Test 7"packoff to 5000 PSI 38. Lay Down 5" Drill Pipe. 39. Change and test Upper Rams to 3 1/2" x5". Test BOPE on 4" and 5"to 5000 psi/Hydril to 2500 psi. 40. Pick up and stand back 4" drill pipe. 41. Pick up 6 1/8" BHA: a. 6 1/8" PDC bit b. 4 3/4" Mud Motor c. Stabilizer d. 4 3/4" MWD/Triple Combo e. Ported Float Sub f. Stabilizer 5 • • g. 3 x 4 3/4"NM Flex Collars 42. RIH on 4" drill pipe to float collar. Test casing to 5000 psi. 43. Drill out float collar, shoe track and float shoe. 44. Drill 20' of new formation. Circulate and condition mud. Perform FIT to minimum 10.5 ppg EMW (10.5 ppg is minimum, take to leak off pressure). 45. Directionally drill 6 1/8" hole to TD at 11,968' MD / 10,024' TVD,per directional plan. a. Note swab and surge pressures of tripping are excessive at this depth. Consider pumping out of the hole on any trip. b. This section will be almost entirely in the productive horizon. c. Note transition zones and reduce ROP when drilling through coals 46. Circulate hole clean with minimum of three bottoms up. Preferred procedure is first circulation on bottom, pull a stand for the next, and same for the third and fourth if necessary. 47. Pump out to 7" shoe or make wiper trip then POH. 48. Pick up Weatherford Triple combo memory shuttle log. RIH on drill pipe to TD. Circulate bottoms up. POH logging as directed to 9 5/8" shoe. —Confirm logging run and depth interval with CIE office. 49. Rig up to run 5"liner. Change upper rams to 5" and test to 5000 psi. 50. Run 5"; 18#; L-80; BTC Liner to bottom. a. Centralizer program to be as follows: i. 1 Solid body spiral centralizer every joint through planned TOC. ii. 1 Solid body spiral centralizer every 4th joint thereafter. b. Break circulation at 5000', 7,500', and every 2000' in open hole. c. Note swab and surge pressures of tripping are excessive with 5" liner in 6 1/8" hole at this depth. d. Top of liner to be 300' inside 7" casing shoe. 51. Circulate and condition hole. Reciprocate liner while circulating. 52. Rig up and test cementers. Cement 5" liner according to program. Continue reciprocating liner while pumping cement. Bump plugs with 3000 psi. Continue pressuring up, setting Liner/Hanger-Packer,per Service Company's Procedure. Release pressure and check floats. Un-sting from liner. a. Ensure cement is a minimum of 1000' above top of highest known hydrocarbons. 53. Circulate out excess cement. 54. POH laying down all 4"drill pipe. 55. Change and test ram to 5000 psi on 3 %2"and 2 3/8". Pick up 4"mill and 5" scraper and RIH picking up 2 3/8 Tubing. 56. Clean out 5" liner to landing collar. Circulate hole clean. Test casing and liner lap to 5000 psi if past 24 hour CIP. Change over to completion fluid using appropriate spacers. 57. POH& stand back tubing. 58. Run CBL. Prepare squeeze program if necessary. 6 • • 59. Pick up TCP completion/packer and jewelry. 60. RIH on 2 3/8"tubing. 61. Run GR gun correlation log. Set TCP on depth and confirm. 62. Set Packer and test tubing to 3000 psi for 30 minutes. Test annulus to 3000 psi for 30 minutes. 63. Nipple down BOPs. Nipple up and test tree. 64. Release rig. 65. Open sliding sleeve and displace tubing to crude oil. Set jet pump in sleeve. 66. Cycle well pressure and fire guns. 67. Flow well. Formation Integrity Test Procedure Surface and Intermediate casing shoes will be tested to Leak-off. Prior to drilling out of casing strings, test BOPs, and casing to the specified pressure listed in the BOP Program section. Plot test and record volume required on the drilling report. Leak-off tests (LOT) are to be conducted as described below: • Drill 20'to 25' of new formation below the casing shoe and condition the mud to the same properties in and out. • Pull drill bit into the casing shoe and close pipe ram preventer. Line up to the choke manifold with a closed choke. • Begin slowly pumping fluid down the drill string at 1/2 bpm while recording casing and drill pipe pressures at 1/2 bbl intervals. • A running plot of pressure versus volume should be kept by the Drill Site Manager while the test is in progress. • Stop pumping when the pressure curve departs form a straight line sufficiently to indicate leakage into the formation. Record as ppg equivalent mud density in the IADC and morning reports. • Monitor and plot pressure drop and time after shut-in for 10 minutes or until the shut-in pressure stabilizes. 7 • Proposed Wellbore Diagram Olson Creek#2 Proposed Completion 1/1/14 3/8" L80 200'TVD 68# BTC 200'MD • 12 1/4"Hole 9 5/8" L-80 1,781'TVD 40# BTC 2000'MD TOL 7200'MD 8.5"Hole 7" L80 6,961'TVD 29# BTC 8500'MD Sliding Sleeve 9,500'MD Hydraulic Set Packer 9,700' XN Nipple @ 9,750' 2 3/8"L80 EUE Tubing J 6 1/8"Hole 5 L80 10,024'TVD 18# BTC 11,967'MD 8 • • Time vs. Depth Plot WF-03 Time vs Depth Chart Rig Drys on Location 0 5 30 15 20 25 30 35 40 45 50 55 60 65 70 0 iii Surfeit ti¢e i 1 2000 3000 cs ND Ufverter,NU$OP,LOT f 4000 j 5000 6000 1 7000 I 8000I 1 ` 10 I 9000 i i I I 10000 Don g.5^HalS e .ctoa 4, 1 11000 401 .449"/IP 12000 13000 - - 14000 • 1 15000 - I 16000 I I 17000 - r18000 , _. . 1 __. • 1I 19000 I 1 9 0 • Directional Plan _ Cook Inlet Energy_ Cook Inlet EnergyBAKER!R 1 Location, Cook Inlet,Alaska(Kenai Peninsula) Sot Olson 2 Sot HUGHES Field Olson Creek lint Well. Olson 2 Facility: Olson Creek Wellbore Ohon2 WelPlan Plot reference wellpath is Olson 2 Verity True vertical depths are referenced to Rig on Olson 2 Slot(RT) Grid System:NAD27/TM Alaska SP,Zone 4(5004),US feet Measured depths are referenced to Rig on Olson 2 Slot(RT) North Reference:Grid north Rig on Olson 2 Slot(RT)to Mean Sea Level:324 4 feet Scale.True distance Mean Sea Level to Mud line(At Slot Olson 2 Slot)0 feet Depths are in feet Coordinates are in feet referenced to Slot Created by:ulricard on 15/JuV2014 Well Profile Data Design Comment MD(II) Inc(°) Az(°) TVD(t) Local N(It) Local E(ft) DLS(°/100t) VS(ft) Tie On 0.00 0.000 283.720 0.00 0.00 0.00 0.00 0.00 End of Tangent 500.00 0.000 283.720 500.00 0.00 0.00 0.00 0.00 End of Build 1888.30 51.050 283.720 1711.77 137.24 -562.12 3.68 578.02 End of Tangent 2013.00 51.050 283.720 1790.16 160.24 -656.33 0.00 674.89 End of 3D Arc 2410.70 37.620 280.834 2074.00 220.01 -927.05 3.41 952.05 End of 3D Arc 2420.90 37.930 280.830 2082.06 221.19 -933.19 3.04 958.30 End of Tangent 7446.50 37.930 280.830 6046.07 801.64 -3967.39 0.00 4047.50 End of 3D Arc 7777.90 27.990 280.400 6323.78 834.90 -4144.37 3.00 4227.57 End of Tangent 11967.90 27.990 280400 10023.67 1189.88 -6078.50 0.00 6193.87 Easting(ft) Scal.1250 1 -70001�__-6000 -5000 -4000 -3000 -2000 -1000 0 100pj000 Ell 1 a t r 1 l� oton 2 WeiN, �� ISM Ira ' D_ A I,'l33"Ain Conductor TD_3 4 100D o End of Tangent yonek_P3 724y_P3 j 4 'a Olson 2 Slot a 1250 368'!10011 `OP". 0 sos 8 625n Cesng "'3.41.1100fl ncr# aa+'' TT24(123.04'1100n End or 3D Arc 0 ..,ISSN 0 2500- '`� -1000 3750- L 5000- 0 In U gg m E 001100ftert > 6250- Tyonek_P3 End of 3D Arc 2 Tin Casing D'' 7500 8750 10000- TD_P3 nd ofTan0ert O 11250. 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W., 8898$888888om):: 88 i9Emi8b9o. 888888 8889889N_843,8351t8 88'8'8882 8o 8„8.8888888ii 1 18888458888 Wri888888 8 2988�83imm88C2 8848 �,'Nt38U-,N888�o m�, m A w N >8803. 2�tN,amw1Am*ST,W98Na8BS8a e,M8w 8<sCS'8,118Nm88mm88 ➢A'N3MwomNW NW mm 2iaa8s...l 88988888888 8888A88 98£398889881141 889 853588-NWAmV8S8 88. 12 • • cell Clearance Report Valli Olson 2 `er#4 pros BAKER Cook Inlet Energy Closest Approach Page 1 of 25 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek I REPORT SETUP INFORMATION Projection System NAD27 I TM Alaska SP,Zone 4(5004), Software System WellArchited®4.0.1 US feet North Reference Grid User Ulricard IScale 0.999946 Report Generated 03/Junt2014 at 15:10 Convergence at slot 1.00°West Database/Source file WA Anchorage Server/Olson 2 WellPlan_CR.xml WELLPATH LOCATION Local coordinates Grid coordinates Geographic coordinates North[ft] East[ft] Easting[US ft] Northing[US ft] Latitude Longitude Slot Location i 0.00 0.00 299832.00 2648980.00 61°14'44.259"N 151°08'11.361"W ,Facility Reference Pt 299832.00 2648980.00 61°14'44.259"N 151°08'11.361"W 'Field Reference Pt 299862.99 2648974.54 61°14'44.211"N 151°08'10.726"W WELLPATH DATUM Calculation method Minimum Curvature Rig on Olson 2 Slot(RT)to Facility Vertical 324.4011 Datum Horizontal Reference Pt Slot Rig on Olson 2 Slot(RT)to Mean Sea Level 324.4011 Vertical Reference Pt Rig on Olson 2 Slot(RT) Rig on Olson 2 Slot(RT)to Mud Line at Slot 324 40tt (Olson 2 Slot) MD Reference Pt Rig on Olson 2 Slot(RT) Field Vertical Reference Mean Sea Level POSITIONAL UNCERTAINTY CALCULATION SETTINGS Ellipse Confidence Limit 3.00 Std Dev Ellipse Start MD 324.401t Surface Position Uncertainty induded Dec lination 17.04°East of TN Dip Angle 74.08° Mag Field Strength 55651 nT Slot Surface Uncertainty @1 SD Horizontal _ 2.0001t Vertical 11.000ft Facility Surface Uncertainty @1SD Horizontal --I20.000ft Vertical '3.000ft Positional Uncertainty values in the WELLPATH DATA table are the projection of the ellipsoid of uncertainty onto the vertical and horizontal planes €0 13 • • ceB Clearance Report iI Olson 2r#4 BAKER _ Cook Inlet Energy Closest Approach Page 2 of 25 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek ANTI-COLLISION RULE Rule Name E-type Closest Approach w/Hole&Csg Limit:0,StdDev:3.00 Rule Based On Ellipsoid Separation w/Surface Uncert _ Plane of Rule Closest Approach Threshold Value 0.008 Subtract Casing&Hole Size yes Apply Cone of Safety no HOLE&CASING SECTIONS-Ref wellbore:Olson 2 Wein Ref Wellpath:Olson 2 Ver#4 StrIng/Diameter Start MD End MD Interval Stmt TVD End TVD Start N/S Start E/W End N/S End E/W [ft] [ft] [ft] [ft] [ft] [ft] [ft] [ft] [ft] _^ 1-1.3375in Conductor 0.00 200.001 200.00 0.00 200.00 0.00 0.00 0.00 0.00 0.625in Casing 0.00 2000.00 2000.00 0.00 1781.99 0.00 0.00 157.84 -646.511 77in Casing 0.00 7500.00 7500.00 0.00 6088.72 0.00 0.00 807.69 -3999.11 Sin Liner 7200.00 11968.00 4768.00 5851.64 NA 773.17 -3818.57 NA NA SURVEY PROGRAM- Ref wellbore:Olson 2 We lPlan Ref Wellpath:Olson 2 Ver#4 Start MD End MD Positional Uncertainty Model Log Name/Comment Wellbore [nl [nl r 324.40 11967.90NaviTrak(MagCon-) Olson 2 WellPlan CALCULATION RANGE&CUTOFF rFrom:0.00ft MD To:11967.908 MD C-C Cutoff(none) OFFSET WELL CLEARANCE SUMMARY(4 Offset Wellpaths selected)Ellipse separations calculated h Closest Approach plane C-C Clearance Distance ACR Ellipse Separation Distance Ref Min C-C Diverging Ref MD of Min Min Ell Sep ACR Offset Offset Offset Offset Offset MD Clear Dist from MD Min Ell Sep Ell Sep Dvrg from Status Facility Slot Well Wellbore Weapath [R] [ft] [ft] [R] [ft] [R] Olson Creek Olson 1 Slot Olson 1 Olscn 1 Olson 1 '205.00 31.15 205.00 417.90 20.41 417.90 PASS Olson Creek Olson 1 Slot Olson 1 PSI Olson 1 PBI Olson 1 PSI 1 205.00 31.15 205.00 417.90 20.411 . 417.90 PASS 'Otter Otter#1 Otter#1 Otter#1A NavtTrakMWD<4436-7021'> 1160.00 38436.41 160.00 68443 38321.981 68443 PASS Otter Otter#1 Otter#1 Otter#1 Otte-#1<0-5686> 1 160.00 38436.41 160.001 68443 38322.09 684.43 PASS €8 14 • • cea Clearance Report VARIII Olson 2 `er#4 pros BAKER _ Cook Inlet Energy_ Closest Approach Page 3 of 25 HUGHES : Di : ► VG . . i CATIO Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek CLEARANCE DATA-Offset Wellbore:Olson 1 Offset Wellpath:Olson 1 Facility:Okm Creek Slot:Olson 1 Slot Welt Olson 1 Threshold Value=0.00 ft t=interpolated/extrapolated statim Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Hark C-C ACR Ellipse ACR [it] [rt] [et] [ft] pt] [rt] [ft] [it] Bearing Clear Dist MASD Sep Status 1°] [n] Ertl [n] 0.00 0.00 0.00 0.00 1530 32.80 -5.49 30.99 100.05 45.46 1.01 44.45 PASS 100.00t 100.00 0.00 0.00 82.58 100.08 -5.04 30.98 99.24 31.39 1.01 30.38 PASS 200.00f 200.00 0.00 0.00 182.56 200.02 -2.48 31.05 94.56 31.15 0.88 30.28 PASS 205.00f 205.00 0.00 0.00 187.50 204.96 -2.28 31.07 94.20 31.15 0.72 30.43 PASS 300.00t 300.00 0.00 0.00 282.43 299.78 2.17 3138 86.05 31.45 0.72 30.73 PASS 400.00t 400.00 0.00 0.00 382.16 399.35 7.83 31.80 76.16 32.76 11.65 21.11 PASS 417.90t 417.90 0.00 0.00 400.00 417.15 8.95 31.90 74.33 33.14 12.72 20.41 PASS 500.00 500.00 0.00 0.00 481.79 498.76 14.50 32.36 65.87 35.48 12.75 22.74 PASS 600.00t 599.93 0.76 -3.12 581.29 597.95 22.22 32.93 59.24 42.00 12.93 29.07 PASS 700.00f 699.45 3.04 -12.45 68039 696.67 30.89 33.44 58.75 53.75 13.44 40.31 PASS 800.00t 798.15 6.83 -27.97 778.67 794.46 40.66 33.69 61.25 70.43 14.12 56.31 PASS 900.00f 895.62 12.11 -49.60 875.84 891.00 51.74 33.61 64.53 92.28 14.72 77.56 PASS 1000.00f 991.46 18.86 -77.27 97150 985.87 64.01 33.23 67.78 119.49 15.49 104.01 PASS 1100.00f 1085.28 27.06 -110.85 106538 1078.80 77.27 32.67 70.72 152.19 16.28 135.90 PASS 1200.00t 1176.69 36.67 -150.20 115735 1169.66 91.49 31.88 73.24 190.28 17.12 173.16 PASS I 1300.001. 1265.31 47.65 -195.17 1246.27 1257.27 106.66 30.80 75.36 233.68 17.97 215.70 PASS 1400.00t 1350.78 59.95 -245.56 1332.04 1341.54 122.63 29.88 77.18 282.64 18.86 263.78 PASS 1500.001 1432.75 73,53 -301.18 141551 1423.27 139.50 28.80 78.70 336.64 19.78 316.86 PASS 1600.00 f 1510.88 88.33 -361.79 1494.07 1499.85 157.00 27.70 80.00 395.65 20.72 374.94 PASS 1700.00t 1584.84 104.29 -427.15 1569A0 1572.86 175.54 26.62 81.08 459.48 21.71 437.78 PASS 1800.00t 1654.34 12133 -496.97 1638.63 1639.51 194.20 2.5.62 82.06 527.86 22.66 505.20 PASS 1888.30 1711.77 137.24 -562.12 1694.42 1692.88 210.45 25.09 82.89 592.06 23.52 568.54 PASS 1900.0Ot 1719.12 139.40 -570.96 1702.02 1700.13 212.74 25.04 82.98 600.80 23.65 577.15 PASS 2000.001. 1781.99 157.84 -646.51 1763.22 1759.14 228.89 24.85 83.96 675.49 24.49 651.01 PASS 2013.00 1790.16 160.24 -656.33 176950 1765.24 230.42 24.90 84.12 685.29 24.46 660.83 PASS 2100.00t 1846.57 175,66 -720.74 1826.40 1820.51 243.92 25.43 84.77 749.73 25.22 724.52 PASS 2200.001 1915.50 191.80 -791.34 189858 1890.85 260.07 26.29 85.23 820.85 26.15 794.70 PASS 2300.001. 1988.58 206.19 -858.05 1972.73 1963.45 275.14 27.18 85.55 888.27, 27.08 861.19 PASS 2400.00f 2065.55 218.77 -920.61 2059.65 2048.89 291.08 27.83 85.64 951.34' 28.11 923.23 PASS 2410.70 2074.00 220.01 -927.05 2068.44 2057.56 292.56 27.87 85.66 957.81 28.19 929.62 PASS €1 15 • i cea Clearance Report Iraiiill Olson 2`er#4 pros BAKER Cook Inlet Energy_ Cbsest Approach Page 4 of 25 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek CLEARANCE DATA-Offset Wellbore:Olson 1 Offset Wellpath:Olson 1 Facility:Ohm Creek Slot:Ohm 1 Slot Welt Olsm 1 Threshold Valu0.00 ft t=interpolatedtextrapolated statim Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Horn C-C ACR Ellipse ACR Ft] [it] k1-] St] [111 St] pt] St1 Bearing Clear Dist MASD Sep Status 11 [R] [ttl 9t] I. 2420.90 ' 2082.06 221.19 -933.19 2076.14 2065.15 293.84 27.90 85.68 963.98 28.27 935.71 PASS 2500.00t 2144.45 230.32 -980.95 213632 2124.57 303.36 28.34 85.86 1012.12 28.86 983.25 PASS 2600.001- 2223.33 241.87 -1041.32 2212.71 2200.13 314.49 29.07 86.12 1073.10 29.61 1043.49 PASS 2700.00} 2302.21 253.42 -1101.70 2292.99 2279.87 323.75 30.15 86.44 1134.25 30.34 1103.91 PASS 2800.001 2381.08 264.97 -1162.07 2377.17 2363.74 330.85 31.10 86.84 1195.11 31.04 1164.07 PASS 2900.001 2459.96 276.52 -1222.45 2456.07 2442.48 335.67 32.01 87.30 1255.97 31.63 1224.35 PASS 3000.001 2538.83 288.07 -1282.82 2541.14 2527.51 338.46 32.86 87.81 1316.69 32.19 1284.50 PASS 3100.001 2617.71 299.62 -1343.20 2615.46 2601.82 338.71 33.52 88.37 137736 32.61 1344.75 PASS 3200.001 2696.59 311.17 -1403.57 2688.72 2675.06 337.46 34.49 88.95 1438.47 32.98 1405.49 PASS 3300.001 2775.46 322.72 -1463.95 2765.27 2751.57 335.36 35.72 89.52 1499.91 33.35 1466.56 PASS 3400.001 2854.34 334.27 -1524.32 2847.69 2833.96 333.25 36.92 90.04 156137 33.77 1527.60 PASS 3500.001- 2933.22 345.82 -1584.70 2925.22 2911.46 331.40 37.99 90.51 1622.89 34.18 1588.71 PASS 3600.001- 3012.09 357.37 -1645.07 3011.72 2997.93 329.50 38.89 90.95 168425 34.67 1649.57 PASS 3700.001 3090.97 368.92 -1705.45 3092.02 3078.21 327.97 39.48 91.34 1745.46 35.15 1710.31 PASS 3800.001 3169.84 380.47 -1765.82 3167.01 3153.19 326.75 40.07 91.70 1806.77 35.61 1771.16 PASS 3900.001- 3248.72 392.02 -1826.20 3248.72 3234.89 325.60 40.74 92.04 1868.17 36.13 1832.04 PASS 4000.001. 3327.60 403.57 -1886.57 3330.99 3317.15 324.65 41.22 92.34 1929.44 36.68 1892.76 PASS 4100.00} 3406.47 415.12 -1946.95 3411.00 3397.16 323.78 41.58 92.63 1990.64 37.23 1953.42 PASS 4200.001 3485.35 426.67 -2007.32 3489.98 3476.13 323.04 41.90 92.90 2051.86 37.78 2014.08 PASS 4300.001 3564.23 438.22 -2067.70 3568.59 3554.74 322.44 42.22 93.14 2113.11 38.35 2074.77 PASS 4400.001- 3643.10 449.77 -2128.07 3647.54 3633.68 322.01 42.56 93.37 2174.41 38.93 2135.48 PASS 4500.001 3721.98 461.32 -2188.45 3730.92 3717.07 321.69 42.82 93.58 2235.64 39.56 2196.07 PASS 4600.001 3800.85 472.87 -2248.82 3817.44 3803.58 321.58 42.85 93.78 2296.66 40.24 2256.42 PASS 4700.001- 3879.73 484.42 -2309.20 3900.15 3886.29 321.58 42.69 93.96 235752 40.89 2316.63 PASS 4800.001 3958.61 495.97 -2369.57 3980.08 3966.23 321.72 42.46 94.13 2418.33 41.54 2376.79 PASS 4900.001. 4037.48 507.52 -2429.95 4069.11 4055.25 ___322.14 42.05 94.29 2479.00 42.27 2436.72 PASS 5000.001 4116.36 519.07 -2490.32 4161.57 4147.71 322.74 41.19 94.44 253931 43.05 2496.26 PASS 5100.001 4195.24 530.62 -2550.70 4242.46 4228.59 32141 40.20 94.57 259939 43.74; 2555.651 PASS 5200.00t 4274.11 542.17 -2611.07 4322.91 4309.03 324.18 39.22 94.70 2659A7 44.43 2615.04PASS 5300.001 4352.99 553.72 -2671.45 4397.92 4384.03 324.68 38.31 94.83 2719.60 45.07 2674.52 PASS €11 16 • • ce6 Clearance Report Faiii1111 Cook Inlet EnergyOlson2 rBAKER Closest Approach Page 5 of 25 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek , CLEARANCE DATA-Offset Wellbore:Olson 1 Offset Wellpsth:Olson 1 Facility:Olson Creek Slot:Olson 1 Slot Welt Olson 1 Threshold Value=0.00 ft t=interpolated/extrapolated statim Ref MD Ref TVD Ref North Ref East Offset NII) Offset TVD Offset North Offset East Hort' C-C ACR Ellipse ACR [ft] [R] [ft] Ft] [R] Ft] Fii [it] Bearing Clear Dist MASD Sep Status P] [t] [it] Ft] 5400.00} 4431.86 565.27 -2731.82 4465.60 4451.71 324.55 37.64 94.97 2779.97 45.65 2734.32 PASS 5500.001 4510.74 576.82 -2792.20 4526.87 4512.98 323.96 37.34 95.11 2840.81 46.16 2794.65_ PASS 5600.001 4589.62 588.37 -2852.57 4603.53 4589.62 322.89 37.22 95.25 290196 46.80 2855.17 PASS 5700.001 4668.49 599.92 -2912.95 4685.99 4672.08 321.70 37.08 95.39 2963.11 47.49 2915.63 PASS 5800.001 4747.37 611.47 -2973.32 4768.02 4754.10 320.58 36.82 95.52 3024.17 48.19 2975.98 PASS 5900.001 4826.25 623.02 -3033.70 4851.96 4838.03 319.55 36.48 95.65 3085.16 48.91 3036.25 PASS 6000.001 4905.12 634.57 -3094.07 4932.01 4918.07 318.48 36.02 95.77 3146.04 49.61 3096.43 PASS 6100.001 4984.00 646.12 -3154.45 5010.04 4996.10 317.42 35.62 95.88 3206.98 50.29 3156.69 PASS 6200.001 5062.87 657.67 -3214.82 5095.40 5081.44 316.40 35.13 95.99 3267.88 51.04 3216.84 PASS 6300.001 5141.75 669.22 -3275.20 5160.00 5146.04 315.64 34.59 96.10 3328.62 51.63 3277.00 PASS 6400.001 5220.63 680.77 -3335.57 5160.00 5146.04 315.64 34.59 96.18 3390.71 51.67 3339.04 PASS 6500.001 5299.50 692.32 -3395.95 5160.00 5146.04 315.64 34.59 96.27 3454.57 51.69 3402.87 PASS 6600.001 5378.38 703.87 -3456.32 5160.00 5146.04 315.64 34.59 96.35 3520.11 51.71 3468.40 PASS 6700.001 5457.25 715.42 -3516.70 5160.00 5146.04 315.64 34.59 96.42 3587.24 51.71 3535.53 PASS 6800.001 5536.13 726.97 -3577.07 5160.00 5146.04 315.64 34.59 96.50 3655.88 51.71 3604.17 PASS 6900.001 5615.01 738.52 -3637.44 5160.00 5146.04 315.64 34.59 96.57 3725.94 51.70 3674.24 PASS 7000.001 5693.88 750.07 -3697.82 5160.00 5146.04 315.64 34.59 96.64 379734 51.68 3745.65 PASS 7100.001 5772.76 761.62 -3758.19 5160.00 I 5146.04 315.64 34.59 96.71 3870.00 51.67 3818.33 PASS 7200.001 5851.64 773.17 -3818.57 5160.00 5146.04 315.64 34.59 96.77 3943.86 51.65 3892.22 PASS 7300.001 5930.51 784.72 -3878.94 5160.00 5146.04 315.64 34.59 96.84 4018.86 51.63 3967.23 PASS 7400.001 6009.39 796.27 -3939.32 5160.00 5146.04 315.64 34.59 96.90 4094.92 51.61 4043.31 PASS 7446.50 6046.07 801.64 -3967.39 5160.00 5146.04 315.64 34.59 96.92 4130.63 51.60 4079.04 PASS 7500.001 6088.72 807.69 -3999.11 5160.00 5146.04 315.64 34.59 96.96 4171.52 51.58 4119.93 PASS 7600.001 6170.80 818.31 -4055.22 5160.00 5146.04 315.64 34.59 97.01 4246.10 51.46 4194.64 PASS 7700.001 6255.76 828.01 -4107.05 5160.00 5146.04 315.64 34.59 97.05 4318.24 51.41 4266.83 PASS 7777.90 6323.78 834.90 -4144.37 5160.00 5146.04 315.64 34.59 97.08 4372.69 51.34 4321.34 PASS 7800.001 _6343.29 836.77 -4154.57 5160.00 5146.04 315.64 34.59 97.09 4387.95 51.32 4336.63 PASS 7900.00 6431.60 845.24 -4200.73 5160.00 5146.04 315.64 34.59 97.13 4457.701 51.19 4406.51 PASS 8000.001 6519.90 853.72 -4246.89 5160.00 5146.04 315.64 34.59 97.16 452839 51.08 4477.51 PASS 8100.001 6608.20 862.19 -4293.05 5160.00 5146.04 315.64 34.59 97.20 4600.56 50.97 4549.59 PASS'j €1 17 • • cels Clearance Report Fara' Olson 2`er#4 pros BAKER Cook Inlet Energy_ Closest Approach Page 6 of 25 HUGHES REFERENCE WELLPATH IDENTIFICATION . Operator Cook Inlet Energy Slot 'Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek CLEARANCE DATA-Offset Wellbore:Olson 1 Offset Wellpath:Olson 1 Facility:Olson Creek Slot:Okra 1 Slat Welk Olson 1 Threshold Value=0A0 ft t=interpolatedtextrapolated statim Ref MD Ref TVD Ref North Ref East Offset MD Onset TVD Offset North Offset East Hartz C-C ACR Ellipse ACR go [ftl 1111 [ttl Ift] [ft] [ft] [a] Bearing Clear Dist MASD Sep Status 11 @'t] [ttl Pi 8200.00} 6696.51 870.66 -4339.21 5160.00 5146.04 315.64 34.59 97.23 467356 50.87 4622.69 PASS 8300.001. 6784.81 879.13 -438537 5160.00 5146.04 315.64 34.59 97.27 4747.54 50.78 4696.77 PASS 8400.00} 6873.11 887.60 -443133 5160.00 5146.04 315.64 34.59 9730 4822.47 50.69 4771.78 PASS 8500.00} 6961.41 896.08 -4477.69 5160.00 5146.04 315.64 34.59 9733 489829 50.62 4847.67 PASS 8600.001- 7049.72 904.55 -4523.86 5160.00 5146.04 315.64 34.59 9736 4974.96 5035 4924.41 PASS 8700.001- 7138.02 913.02 -4570.02 5160.00 5146.04 315.64 34.59 9739 5052.45 5030 5001.96 PASS 8800.00} 7226.32 921.49 -4616.18 5160.00 5146.04 315.64 34.59 97.42 5130.72 50.45 5080.27 PASS 8900.001- 7314.63 929.96 -466234 5160.00 5146.04 315.64 34.59 97.45 5209.73 50.41 5159.32 PASS 9000.00} 7402.93 938.44 -470850 5160.00 5146.04 315.64 34.59 97.48 5289.45 5039 5239.07 PASS 9100.001- 7491.23 946.91 -4754.66 5160.00 5146.04 315.64 34.59 97.51 5369.86 5037 5319.48 PASS 9200.001- 7579.54 955.38 -4800.82 5160.00 5146.04 315.64 34.59 9754 5450.91 5037 5400.54 PASS 9300.00} 7667.84 963.85 -4846.98 5160.00 5146.04 315.64 34.59 9736 553258 5038 5482.20 PASS 9400.00} 7756.14 972.32 -4893.14 5160.00 5146.04 315.64 34.59 9739 5614.84 5039 5564.45 PASS 9500.001- 7844.44 980.80 -493930 5160.00 5146.04 315.64 34.59 97.62 5697,67 50.42 5647.25 PASS 9600.001- 7932.75 989.27 -4985.46 5160.00 5146.04 315.64 34.59 97.64 5781.04 50A6 5730.58 PASS 9700.001- 8021.05 997.74 -5031.62 5160.00 5146.04 315.64 34.59 97.67 5864.94 5051 5814.42 PASS 9800.00} 8109.35 1006.21 -5077.78 5160.00 5146.04 315.64 34.59 97.69 594933 5037 5898.75 PASS 9900.001- 8197.66 1014.68 -5123.95 5160.00! 5146.04 315.64 34.59 97.72 6034.20 50.65 5983.55 PASS 10000.00} 8285.96 1023.16 -5170.11 5160.00 5146.04 315.64 34.59 97.74 611952 50.73 6068.79 PASS 10100.001- 8374.26 1031.63 -521627 5160.00 5146.04 315.64 34.59 97.77 6205.29 50.82 6154.46 PASS 10200.00} 8462.56 1040.10 -5262.43 5160.00 5146.04 315.64 34.59 97.79 6291.47 50.93 6240.54 PASS 10300.001- 8550.87 1048.57 -530839 5160.00 5146.04 315.64 34.59 97.81 6378.06 51.04 6327.01 PASS 10400.001- 8639.17 1057.05 -5354.75 5160.00 5146.04 315.64 34.59 97.83 6465.03 51.17 6413.86 PASS 10500.00} 8727.47 1065.52 -5400.91 5160.00 5146.04 315.64 34.59 97.86 655238 5131 6501.07 PASS 10600.00} 8815.78 1073.99 -5447.07 5160.00 5146.04 315.64 34.59 97.88 6640.08 51.45 6588.63 PASS 10700.001- 8904.08 1082.46 -5493.23 5160.00 5146.04 315.64 34.59 97.90 6728.13 51.61 6676.51 PASS 10800.00} 8992.38 1090.93 -553939 5160.00 5146.04 315.64 34.59 97.92 681630 51.78 6764.72 PASS 10900.001. 9080.69 1099.41 -558535 5160.00 5146.04 315.64 34.59 97.94 6905.20 51.96 6853.24,PASS 11000.001- 9168.99 1107.88 -5631.71 5160.00 5146.04 315.64 34.59 97.96 6994.19 52.15 6942.05'PASS 11100.001- 9257.29 1116.35 -5677.87 5160.00 5146.04 315.64 34.59 97.98 7083.49 5235 7031.14 PASS f €1 18 0 • da Clearance Report iU Olson 2r a BAKER Cook Inlet Energy_ Closest Approach Page 7 of 25 HUGHES 'r' ' '>''e ` '` ..ATH IDENTIFICATION Operator Cook Inlet Energy 'Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek CLEARANCE DATA-Offset Wellbore:Olson 1 Offset Wellpath:Olson 1 Facility:Olson Creek Slot:Olson 1 Slot Welt Olson 1 Threshold Value=0.00 ft t=interpolated/extrapolated station Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Harts C-C ACR Ellipse ACR [it] [It] [R] [R] [It] lit] [ft] VII Bearing Clear Dist MAID Sep Status [0] [ft] [ft] [ft) 11200.001- 9345.59 1124.82 -5724.03 5160.00 5146.04' 315.64 34.59 98.00 7173.06 52_55 7120.51 PASS 11300.00} 9433.90 1133.29 -5770.20 5160.00 5146.04 315.64 34.59 98.02 7262.91 52.77 7210.14 PASS 11400.00} 9522.20 1141.77 -5816.36 5160.00 5146.04 315.64 34.59 98.04 7353.02 53.00 7300.02 PASS 11500.00} 9610.50 1150.24 -5862.52 5160.00 5146.04 315.64 34.59 98.06 7443.38 53.24 7390.14 PASS 11600.00} 9698.81 1158.71 -5908.68 5160.00 5146.04 315.64 34.59 98.07 7533.98 53.48 7480.50 PASS 11700.00} 9787.11 1167.18 -5954.84 5160.00 5146.04 315.64 34.59 98.09 7624.82 53.74 7571.08 PASS 11800.00} 9875.41] 1175.65 -6001.00 5160.00 5146.04 315.64, 34.59 98.11 7715.89 54.00 7661.89 PASS 11900.00} 9963.721 1184.13 -6047.16 5160.00 5146.04 315.64 34.59 98.13 7807.17 54.28 7752.90 PASS 11967.90 10023.67 1189.88 -6078.50 5160.00 5146.04 315.64 34.59 98.14 7869.28 54.47 7814.81 PASS POSITIONAL UNCERTAINTY- Offset Wellbore:Olson 1 Offset Wellpath:Olson 1 Slot Surface Uncertainty @1SD Horizontal 2.0008 Vertical 1.000ft ]Facility Surface Uncertainty @1SD Horizontal 20.000ft Vertical 3.00031 HOLE&CASING SECTIONS-Offset Wellbore:Olson 1 Offset Weilpath:Olson 1 String/Diameter Start MD End MD Interval Start TVD End TVD Start N/S Start E/W End N/S End ERV [n] [ft] [n] [n] [n] [n] [n] [n] [n] 110.75in Conductor 15.30 157.00 141.70 48.10 189.78 -3.35 1 8.891 -2.70 18.90 17-.625in Casing 15.30 1600.00 1584.70 48.10 1617.67 -3.35 18.891 54.28 17.42 1-6.75in Open Hole 15.30 1600.00 1584.70 48.10 1617.67 -3.35 18.89' 54.28 17.42 6.75in Open Hole 1600.00 5643.00 4043.00 1617.67 NA 54.28 17.42 NA NA €1 19 • Clearance Report IMAM Olson 2Ver#4BAKER _ Cook Inlet Energy Closest Approach Page 8 of 25 HES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek WELLPATH COMPOSITION-Offset Wellbore Olson 1 Offset Wellpath:Olson 1 Start MD End MD Positional Uncertainty Model Log Name/Conunent Wellbore [ft] _j_ _1] 15.30 1600.00 Generic gyro-continuous(Standard) Olson 1 PB1 Gyro<0-1850> Olson 1 PB1 1600.00 5160.00 ISCWSA MWD,Rev.2,axial magnetic correction(Standard) Olson 1 Olson 1 OFFSET WELLPATH MD REFERENCE- Offset Wellbore:Olson 1 Offset Wellpath:Olson 1 MD Reference:Rig on Olson 1(RKB) OfJtet TVD&local coorrffnates use Reference Wellpath settings (See WELLPATH DATUM on page I of this report) Ellipse Start MD 339.7011 €3 20 • • aeB Clearance Report FARO Olson 2`'erg BAKER _ Cook Inlet Energy Closest Approach Page 9 of 25 HUGHES REFERENCE V.ELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek CLEARANCE DATA-Offset Wellbore:Olson 1 PB1 Offset Wellpath:Olson 1 PB1 I Facility:Oism Creek Si.t:Olson 1 Slot Welt Olson 1 PB1 Threshold Value=0.00 ft t=interpolated/extrapolated station Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Hors C-C ACR Ellipse ACR [ft] 1rt] [rt] [ft] lit] [ft] [ft] [R] Bearing Clear Dist MASD Sep Status M [R] Kg [R] 0.00 0.00 0.00 0.00 1530 32.80 -5.49 3099 100.05 45.46 1.01 44.45 PASS 100.00} 100.00 0.00 0.00 82.58 100.08 -5.04 3098 99.24 3139 1.01 30.38 PASS 200.00} 200.00 0.00 0.00 18256 200.02 -2.48 31.05 94.56 31.15 0.88 30.28 PASS 205.001- 205.00 0.00 0.00 18750 204.96 -2.28 31.07 94.20 31.15 0.72 30.43 PASS 300.00} 300.00 0.00 0.00 282.43 299.78 2.17 31.38 86.05 31.45 0.72 30.73 PASS 400.00} 400.00 0.00 0.00 382.16 399.35 7.83 31.80 76.16 32.76 11.65 21.11 PASS 417.90} 417.90 0.00 0.00 400.00 417.15 8.95 31.90 74.33 33.14, 12.72 20.41 PASS 500.00 500.00 0.00 0.00 481.79 498.76 14.50 3236 65.87 35.48' 12.75 22.74 PASS 600.00} 599.93 0.76 -3.12 581.29 597.95 22.22 32.93 59.24 42.00 12.93 29.07 PASS 700.00} 699.45 3.04 -12.45 68039 696.67 30.89 33.44 58.75 53.75 13.44 40.31 PASS 800.00} 798.15 6.83 -27.97 778.67 794.46 40.66 33.69 61.25 70.43 14.12 56.31 PASS 900.00} _895.62 12.11 -49.60 875.84 891.00 51.74 33.61 64.53 92.28 14.72 77.56 PASS 1000.00} 991.46 18.86 -77.27 97150 985.87 64.01 33.23 67.78 119.49 15.49 104.01 PASS 1100.00} 1085.28 27.06 -110.85 106538 1078.80 77.27 32.67 70.72 152.19 16.28 135.90 PASS 1200.00} 1176.69 36.67 -150.20 115735 1169.66 91.49 31.88 73.24 190.28 17.12 173.16 PASS 1300.00} 1265.31 47.65 -195.17 1246.27 1257.27 106.66 30.80 75.36 233.68 17.97 215.70 PASS 1400.00} 1350.78 59.95 -245.56 1332.04 1341.54 122.63 29.88 77.18 282.64 18.86 263.78 PASS 1500.001. 1432.75 73.53 -301.18 141531 1423.27 139.50 28.80 78.70 336.64 19.78 316.86 PASS 1600.00} 1510.88 88.33 -361.79 1494.07 1499.85 157.00 27.70 80.00 395.65 20.72 374.94 PASS 1700.00} 1584.84 104.29 -427.15 1569.40 1572.86 175.54 26.62 81.08 459.48 21.71 437.78 PASS 1800.00} 1654.34 121.33 -496.97 1639.66 1640.50 194.49 2556 82.03 527.82 22.74 505.08 PASS 1888.30 1711.77 137.24 -562.12 1697.25 1695.58 211.30 24.82 82.81 591.82 23.68 568.14 PASS 1900.00} 1719.12 139.40 -570.96 1704.61 1702.59 213.53 24.73 82.91 600.52 23.81 576.71 PASS 2000.00} 1781.99 157.84 -646.51 1767.03 1761.77 233.36 24.10 83.58 675.16 24.82 650.34 PASS 2013.00 1790.16 160.24 -656.33 1775.10 1769.39 236.04 24.03 83.64 684.89 24.84 660.05 PASS 2100.00} 1846.57 175.66 -720.74 1830.72 1821.59 255.22 23.62 83.90 749.02 25.78 723.24 PASS 1. 2200.00} 1915.50 191.80 -791.34 1898.12 1884.26 280.01._11 23.21 83.82 819.91 26.93 792.99 PASS 2300.00} 1988.58 206.19 -858.05 1967.91 1948.38 307.56 22.82 83.44 887.60 28.14 859.46,PASS 2400.00} 2065.55 - 218.77 -920.61 2039.63 2013.39 337.83 22.46 82.81 951.99 29.37 922.62 PASS 2410.70 2074.00 a220.01 -927.05 2048.62 2021.50 341.73 22.41 82.70 958.67 29.52 929.15 PASS €1 I 21 0 • cell Clearance Report F/1till! Cook Inlet EnergyOlson 2 rBAKER _ Closest Approach Page 10 of 25 NVGNES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPtan Facility Olson Creek CLEARANCE DATA-Offset Wellbore:Olson 1 PB1 Offset Weilpath:Olson 1 PB1 Facility:Olson Creek Slat:Okm 1 Slat Welk Olson 1 PB1 Threshold Value=0.00 ft }=htespolated/extrapolated station Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Hartz C-C ACR Ellipse ACR lit] EftI Ift] Itt] lit] Ift] Ift] I<t] Bearing Clear Dist MASD Sep Status P] In] [ft] Ertl 2420.90 2082.06 221.19 -933.19 2057.21 2029.24 345.44 22.36 82.59 965.04 29.67 935.37 PASS 2500.00} 2144.45 230.32 -980.95 2131.48 2096.60 376.69 21.56 81.69 101426 30.99 983.27 PASS 2600.00} 2223.33 241.87 -1041.32 2218.11 2176.34 410.51 19.92 80.97 107539 32.58 1043.01 PASS 2700.00} 2302.21 253.42 -1101.70 2313.11 2264.88 444.88 17.71 80.30 1136.27 34.38 1101.89 PASS 2800.00} 2381.08 264.97 -1162.07 2407.16 2353.72 475.57 14.85 79.86 119593 36.14 1159.79 PASS 2900.00} 2459.96 276.52 -1222.45 2501.22 2443.43 503.63 11.31 79.57 125439 37.87 1216.72 PASS 3000.00} 2538.83 288.07 -1282.82 2590.06 2528.79 527.98 7.79 79.47 1312.76 39.45 1273.31 PASS 3100.00} 2617.71 299.62 -1343.20 2677.61 2613.62 549.36 4.21 79.50 137036 40.92 1329.44 PASS 3200.00} 2696.59 311.17 -1403.57 2768.78 2702.59 568.88 0.64 79.60 1427.68 42.35 1385.33 PASS 3300.00} 2775.46 322.72 -1463.95 2861.17 2793.33 585.83 -3.23 79.79 148433 43.67 1440.66 PASS 3400.00} 2854.34 334.27 -1524.32 2956.81 2887.68 600.80 -7.59 80.03 154033 44.93 1495.40 PASS 3500.00} 2933.22 345.82 -1584.70 3050.15 2980.10 613.05 -12.13 80.36 1595.80 46.05 1549.75 PASS 3600.00} 3012.09 357.37 -1645.07 3125.59 3055.02 621.22 -15.69 80.80 1651.16 46.88 1604.28 PASS 3700.00} 3090.97 368.92 -1705.45 3200.11 3129.20 627.56 -18.50 81.28 1707.09 47.61 1659.48 PASS 3800.00} 3169.84 380.47 -1765.82 3275.13 3204.05 632.14 -20.72 81.79 1763.49 48.24 1715.25 PASS 3900.00} 3248.72 392.02 -1826.20 3346.74 3275.62 633.89 -22.33 82.36 1820.20 48.71 1771.49 PASS 4000.00} 3327.60 403.57 -1886.57 3425.73 3354.60 634.07 -23.59 82.95 187738 49.14 1828.25 PASS 4100.00} 3406.47 415.12 -1946.95 3505.71 3434.56 632.67 -24.60 83.54 1934.82 49.49 1885.34 PASS 4200.00} 3485.35 426.67 -2007.32 3592.58 3521.35 629.24 -25.92 84.16 1992.06 49.78 1942.27 PASS 4300.00} 3564.23 438.22 -2067.70 3662.70 3591.37 625.78 -26.77 84.75 2049.70 50.00 1999.70 PASS 4400.00} 3643.10 449.77 -2128.07 3735.59 3664.16 621.94 -27.36 85.32 2107.86 50.21 2057.65 PASS 4500.00} 3721.98 461.32 -2188.45 3800.32 3728.77 617.98 -27.52 85.85 2166.61 50.39 2116.22 PASS 4600.00} 3800.85 472.87 -2248.82 3887.74 3815.98 611.95 -27.62 86.42 2225.60 50.60 2174.99 PASS 4700.00} 3879.73 484.42 -2309.20 3973.15 3901.20 606.17 -28.06 86.95 2284.48 50.84 2233.64 PASS 4800.00} 3958.61 495.97 -2369.57 4052.73 3980.59 600.75 -28.50 87.44 234351 51.08 2292.43 PASS 4900.00} 4037.48 507.52 -2429.95 4131.14 4058.81 595.29 -29.00 87.91 2402.64 51.32 2351.32 PASS 5000.00} 4116.36 519.07 -2490.32 4215.61 4143.09 589.61 -29.62 88.36 2461.85 51.62 2410.24 PASS 5100.00} 4195.24 530.62 -2550.70 4298.67 4225.97 584.23 -30.46 88.78 2520.99 51.93 2469.06 PASS 5200.00} 4274.11 542.17 -2611.07 4390.65 4317.74 578.24 -31.63 89.20 2580.06 52.28 2527.78 PASS 1 5300.00} 4352.99 553.72 -2671.45 4479.68 4406.59 572.74 -33.28 89.59 2638.78 52.66 2586.12 PASS €2 22 0 • aeB Clearance Report FARO Cook Inlet EnergyOlson 2 rBAKER Closest Approach Page 11 of 25 HES IN: 'i''2' ` '., 'A ` 1 A IO• . a ' LI.Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek CLEARANCE DATA-Offset wellbore:Olson 1 PB1 Offset Wellpath:Olson 1 PBI Facility:Olson Creek Slot:Olsm 1 Slat Welt Olson 1 PB1 Threshold Value=0.00 ft t=Interpolated!extrapolated station Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Horiz C-C ACR Ellipse ACR [ft] [ft] 8t] 8't] [ft] [R] [rt] [ft] Bearing Clear Dist MASD Sep Status ll [ft] [ft] l<t] 5400.00t 4431.86 565.27 -2731.82 4569.04 4495.76 567.34 -35.19 89.96 269739 53.07 2644.32 PASS 5500.001 4510.74 576.82 -2792.201. 4640.88 4567.46 563.09 -36.89 90.29 275592 53.41 2702.51 PASS 5600.001 4589.62 588.37 -2852.57 4727.06 4653.46 557.87 -38.75 90.62 2814.71 53.83 2760.88 PASS 5700.001 4668.49 599.92 -2912.95 4828.30 4754.47 551.69 -41.56 90.96 2873.07 54.33 2818.75 PASS 5800.001 4747.37 611.47 -2973.32 4905.66 4831.63 546.70 -43.91 91.27 293133 54.72 2876.62 PASS 5900.001- 4826.25 623.02 -3033.70 5008.83 4934.53 540.05 -47.49 91.59 298932 55.24 2934.08 PASS 6000.001 4905.12 634.57 -3094.07 5089.39 5014.84 534.57 -50.55 91.88 3047.14 55.67 2991.47 PASS 6100.001. 4984.00 646.12 -3154.45 5183.44 5108.58 527.92 -54.33 92.18 3104.86 56.16 3048.70 PASS 6200.001- 5062.87 657.67 -3214.82 5288.16 5212.91 520.43 -59.31 92.49 3162.05 56.73 3105.32 PASS 6300.001 5141.75 669.22 -3275.20 5377.49 5301.89 513.96 -63.86 92.77 3219.07 57.24 3161.83 PASS 6400.001 5220.63 680.77 -3335.57 5477.89 5401.86 506.64 -69.64 93.05 327539 57.81 3217.77 PASS 6500.00} 5299.50 692.32 -3395.95 5533.00 5456.73 502.61 -72.87 93.27 3332.20 58.17 3274.03 PASS 6600.001- 5378.38 703.87 -3456.32 5533.00 5456.73 502.61 -72.87 93.40 339034 58.23 3332.11 PASS 6700.001- 5457.25 715.42 -3516.70 5533.00 5456.73 502.61 -72.87 93.54 345039 58.26 3392.13 PASS 6800.001 5536.13 726.97 -3577.07 5533.00 5456.73 502.61 -72.87 93.66 3512.27 58.28 3453.99 PASS 6900.001- 5615.01 738.52 -3637.44 5533.00 5456.73 502.61 -72.87 93.79 3575.88 58.29 3517.59 PASS 7000.001 5693.88 750.07 -3697.82 5533.00 5456.73 502.61 -72.87 93.91 3641.12 58.28 3582.84 PASS 7100.001 5772.76 761.62 -3758.19 5533.00 5456.73 502.61 -72.87 94.02 370791 58.26 3649.65 PASS 7200.001. 5851.64 773.17 -3818.57 5533.00 5456.73 502.61 -72.87 94.13 3776.17 58.23 3717.93 PASS 7300.001 5930.51 784.72 -3878.94 5533.00 5456.73 502.61 -72.87 94.24 3845.81 58.20 3787.62 PASS 7400.001 6009.39 796.27 -3939.32 5533.00 5456.731 502.61 -72.87 94.34 3916.77 58.15 3858.62 PASS 7446.50 6046.07 801.64 -3967.39 5533.00 5456.731 502.61 -72.87 94.39 3950.20 58.13 3892.06 PASS 7500.001 6088.72 807.69 -3999.11 5533.00 5456.731 502.61 -72.87 94.44 3988.47 58.10 3930.36 PASS 7600.001 6170.80 818.31 -4055.22 5533.00 5456.73' 502.61 -72.87 94.53 4058.16 57.95 4000.21 PASS 7700.001 6255.76 828.01 -4107.05 5533.00 5456.73 502.61 -72.87 94.61 412.5.40 57.86 4067.54 PASS 7777.90 6323.78 834.90 -4144.37 5533.00 5456.73 502.61 -72.87 94.67 4176.04 57.76 4118.28 PASS y{ 7800.001 6343.29 836.77 -4154.57 5533.00 5456.73 502.61 -72.87 94.68 4190.22 57.73 4132.49 PASS 7900.001 6431.60 845.24 -4200.73 5533.00 5456.73 502.61 -72.87 94.75 4255.23 57.56 4197.68 PASS III 8000.001 6519.90 853.72 -4246.89 5533.00 5456.73 502.61 -72.87 94.81 432158 57.39 4264.19 PASS 8100.001 6608.20 862.19 -4293.05 5533.00 5456.73 502.61 -72.87 94.87 4389.21 57.22 4331.98 PASS €1 23 • • cea Clearance Report I ra ii II Cook Inlet EnergyOlson 2 VerBAKER - Closest Approach Page 12 of 25 HUGHES Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek CLEARANCE DATA-Offset Wellbore:Olson 1 PB1 Offset Wellpath:Olson 1 PB1 Facility:Olsm Creek Slot:Olson 1 Slot Welt Olson 1 PBI Threshold Valoe0.00 it t=interpolatedrextrapolated station Ref MD Ref TVD Rel North Ref East Offset MD Offset TVD Offset North Off set East Hort: C-C ACR Ellipse ACR @'t] [ft] [R] [ft] pt] [ft] [ft] [R] Bearing Clear Dist MASD Sep Status 19 pi [h] [ft] 8200.00} 6696.51 870.66 -433921 5533.00 5456.73 502.61 -72.87 9493 4458.05 57.06 4400.98 PASS 8300.00} 6784.81 879.13 -438537 5533.00 5456.73 502.61 -72.87 9499 4528.05 56.91 4471.14 PASS 8400.00} 6873.11 887.60 -443133 5533.00 5456.73 502.61 -72.87 95.05 4599.17 56.76 4542.40 PASS 8500.00} 6961.41 896.08 -4477.69 5533.00 5456.73 502.61 -72.87 95.10 467134 56.62 4614.72 PASS 8600.00} 7049.72 904.55 -4523.86 5533.00 5456.73 502.61 -72.87 95.16 4744.52 56.49 4688.03 PASS 8700.00} 7138.02 913.02 -4570.02 5533.00 5456.73 502.61 -72.87 95.21 4818.66 5636 4762.30 PASS 8800.00} 7226.32 921.49 -4616.18 5533.00 5456.73 502.61 -72.87 95.27 4893.73 56.25 4837.48 PASS 8900.00} 7314.63 929.96 -466234 5533.00 5456.73 502.61 -72.87 9532 4969.67 56.14 4913.53 PASS 9000.00} 7402.93 938.44 -470830 5533.00 5456.73 502.61 -72.87 9537 5046.46 56.04 4990.41 PASS 9100.00} 7491.23 946.91 -4754.66 5533.00 5456.73 502.61 -72.87 95.42 5124.04 5595 5068.09 PASS 9200.00} 7579.54 955.38 -4800.82 5533.00 5456.73 502.61 -72.87 9.5.47 520239 55.88 5146.51 PASS 9300.00} 7667.84 963.85 -4846.98 5533.00 5456.73 502.61 -72.87 95.52 5281.47 55.81 5225.66 PASS 9400.00} 7756.14 972.32 -4893.14 5533.00 5456.73 502.61 -72.87 9557 5361.25 55.75 5305.49 PASS 9500.00} 7844.44 980.80 -493930 5533.00 5456.73 502.61 -72.87 95.61 5441.69 55.71 5385.99 PASS 9600.00} 7932.75 989.27 -4985.46 5533.00 5456.73 502.61 -72.87 95.66 5522.78 55.67 5467.11 PASS 9700.00} 8021.05 997.74 -5031.62 5533.00 5456.73 502.61 -72.87 95.70 5604.48 55.65 5548.83 PASS 9800.00} 8109.35 1006.21 -5077.78 5533.00 5456.73 502.61 -72.87 95.75 5686.76 55.64 5631.12 PASS 9900.00} 8197.66 1014.68 -512395 5533.00 5456.73 502.61 -72.87 95.79 5769.60 55.64 5713.96 PASS 10000.00} 8285.96 1023.16 -5170.11 5533.00 5456.73 502.61 -72.87 9.5.83 5852.98 55.65 5797.33 PASS 10100.00} 8374.26 1031.63 -5216.27 5533.00 5456.73 502.61 -72.87 95.87 5936.87 55.67 5881.20 PASS 10200.00} 8462.56 1040.10 -5262.43 5533.00 5456.73 502.61 -72.87 95.91 6021.25 55.71 5965.54 PASS 10300.00} 8550.87 1048.57 -530859 5533.00 5456.73 502.61 -72.87 95.95 6106.11 55.75 6050.35 PASS 10400.00} 8639.17 1057.05 -5354.75 5533.00 5456.73 502.61 -72.87 95.99 6191.41 55.81 6135.60 PASS 10500.00} 8727.47 1065.52 -5400.91 5533.00 5456.73 502.61 -72.87 96.03 6277.15 55.88 6221.28 PASS 10600.00} 8815.78 1073.99 -5447.07 5533.00 5456.73 502.61 -72.87 96.07 636331 55.96 6307.35 PASS 10700.00} 8904.08 1082.46 -549323 5533.00 5456.73 502.61 -72.87 96.11 6449.87 56.05 6393.82 PASS 10800.00} 8992.38 1090.93 -553939 5533.00 _ 5456.73 502.61 -72.87 96.14 6536.81 56.15 6480.66 PASS 10900.001' 9080.69 1099.41 -558535 5533.00 5456.73 502.61 -72.87 96.18 6624.12 56.26 6567.85 PASS 11000.00} 9168.99 1107.88 -5631.71 5533.00 - 5456.73 502.61 -72.87 9621 6711.78 5639 6655.39 PASS 11100.00} 9257.29 1116.35 -5677.87 5533.00 IF 5456.73 502.61 -72.87 9625 6799.78 5652 6743.26 PASS €1 24 • • eco Clearance Report IISR111 Cook Inlet Ener Olson 2 rBAKER Energy Closest Approach Page 13 of 25 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek CLEARANCE DATA-Offset Wellbore:Olson 1 PB1 Offset Wellpath:Olson 1 PB1 Facility:Olson Creek Slot:Olson 1 Slot Welt Olson 1 PB1. Threshold Value=0.o0 R t=loterpolatedie[trapolated station Ref M1) Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Hark C-C ACR Ellipse ACR [R] [it] [R] [R] in] [ft] lilt] [ft] Bearing Clear Dist MASD Sep Status P] lit] [rt] [ftl 11200.00} 9345.59 1124.82 -5724.03 5533.00 5456.73 502.61 -72.87 9628 6888.11 56.67 6831.45 PASS 11300.001' 9433.90 1133.29 -5770.20 5533.00 5456.73 502.61 -72.87 9632 6976.76 56.83 6919.93 PASS! 11400.00} 9522.20 1141.77 -5816.36 5533.00 5456.73 502.61 -72.87 96.35 7065.71 56.99 7008.72 PASS 1 11500.00} 9610.50 1150.24 -5862.52 5533.00 5456.73 502.61 -72.87 9638 7154.95 57.17 7097.78 PASS! 11600.00} 9698.81 1158.71 -5908.68 5533.00 5456.73 502.61 -72.87 96.42 7244.47 5736 7187.11 PASS 11700.00} 9787.11 1167.18 -5954.84 5533.00 5456.73 502.61 -72.87 96.45 7334.26 57.56 7276.71 PASS 11800.00} 9875.41 1175.65 -6001.00 5533.00 5456.73 502.61 -72.87 96.48 7424.32 57.77 7366.55 PASS 11900.00} 9963.72 1184.13 -6047.16 5533.00 5456.73 502.61 -72.87 96.51 7514.62 57.98 7456.64 PASS i 11967.90 10023.67 1189.88 -6078.50 5533.00 5456.73 502.61 -72.87 9633 7576.08 58.14 7517.94 PASS POSITIONAL UNCERTAINTY- Offset Wellbore Olson 1 PB1 Offset Wdlpath:Olson 1 PB1 Slot Surface Uncertainty@1SD Horizontal 12.00011 Vertical 1.00011 - Facility Surface Uncertainty @1SD Horizontal 120.00011 Vertical 3.00011 HOLE&CASING SECTIONS-Offset Wellbore:Olson 1 PB1 Offset Wellpath:Olson 1 PB1 String/Diameter Start MD End MD Interval Stay TVD End TVD Start N/S Start VW End N/S End E/W [n] [ft] [rt] [n] [B] [ill fit] [n] fill 110.75in Conductor 15.30 157.00 141.70 48.10 189.78 -3.35 18.89 -2.70 18.90 r7.625in Casing 15.30 1998.00; 1982.70 48.10 1991.07 -3.35 18.89 95.87 16.36 r6.75inOpen Hole 15.30 5715.00( 5699.70 48.10 NA -3.35 18.89 NA NA Ell 25 • • aB Clearance Report resits Olson 2r BAKER Cook Inlet Energy_ Closest Approach Page 14 of 25 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek WELLPATH COMPOSITION-Offset Wellbore:Olson 1 PB1 Offset Wellpath:Olson 1 PB1 Start MD End MD Positional Uncertainty Model Log blame/Comment Wellbore [ft] [It] _ 1530 1850.00 Generic gyro-continuous(Standard) Olson 1 PB1 Gyro<0-1850> Olson 1 PB1 18.50.00 5533.00 ISCWSA MWD,Rev.2,axial magnetic correction(Standard) Olson 1 PB1 MWD<2037-5533> Olsen 1 PB1 OFFSET WELLPATH MD REFERENCE- Offset Wellbore:Olson 1 PB1 Offset Wellpath:Olson 1 PB1 MD Reference:Rig on Olson 1(RKII) Offset TVD&local coordinates use Reference Wellpath settings i (See WELLPATH DATUM on page 1 of this report) Ellipse Start MD ;339.7011 €8 26 II) • 0:6 Clearance Report FARIII Olson 2r BAKER _ Cook Inlet Energy Approach Closest Page 15 of 25 HUGHES - ` . ' ` IDENTIFICATION Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WeilPlan Facility Olson Creek CLEARANCE DATA-Offset Wellbore:Otter#1A Offset WeUpotlt:NavlTrak MWD<4436-7021'> Facility:Otter Slot Otter#1 Welt Otter#1 Threshold Valie0.00 ft }=interpolated/extrapolated station Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Off set North Offset East Hark C-C ACR Ellipse ACR [ft] pi [n] St] [ft] [ft] [ft] [ft] Bearing Clear Dist MASD Sep Status Pi [n] iii [n] 0.00 0.00 0.00 0.00 0.00 149.15 26741.81 2760837' 45.91 38436.70 1.11 3843558 PASS 100.001 100.00 0.00 0.00 0.00 149.15 26741.81 27608.57 45.91 38436.44 1.11 3843532 PASS 160.00} 160.00 0.00 0.00 10.00 159.15 26741.81 27608.56 45.91 38436.41 1.11 38435.29 PASS 200.001 200.00 0.00 0.00 31.90 181.05 26741.85 27608.54 45.91 38436.42 1.11 3843530 PASS 300.001- 300.00 0.00 0.00 94.63 243.78 26742.14 27608.34 45.91 38436.52 0.80 38435.71 PASS 400.00} 400.00 0.00 0.00 157.35 306.49 26742.74 27607.93 45.91 38436.71 61.10 38375.61 PASS 500.00 500.00 0.00 0.00 229.59 378.73 26743.77 27607.23 45.91 38437.00 61.10 38375.90 PASS 600.001- 599.93 0.76 -3.12 322.09 471.20 26745.45 27606.02 45.91 38439.03 61.11 38377.92 PASS 684.431' 684.00 2.59 -1059 400.00 549.08 26747.14 27604.75 45.92 38443.42 121.44 38321.98 PASS 700.00} 699.45 3.04 -12.45 412.14 56122 26747.43 27604.53 45.92 38444.50 121.44 38323.05 PASS 800.001- 798.15 6.83 -27.97 489.79 638.83 26749.33 27603.11 45.94 38453.39 121.48 38331.91 PASS 900.001' 895.62 12.11 -49.60 566.62 715.62 26751.36 27601.62 45.96 38465.70 121.53 38344.16 PASS 1000.001. 991,46 18.86 -77.27 660.65 80939 26753.98 27599.71 45.99 38481.36 121.61 38359.75 PASS 1100.001 1085.28 27.06 -110.85 767.06 91594 26756.99 27597.49 46.03 38500.25 121.71 3837834 PASS 1200.00} 1176.69 36.67 -15020 877.67 1026.48 26760.12 27595.11 46.08 38522.30 121.85 38400.45 PASS 1300.001- 1265.31 47.65 -195.17 988.18 1136.92 26763.21 27592.68 46.13 38547.41 122.05 3842536 PASS 1400.00} 1350.78 5995 -24536 1102.42 1251.08 26766.37 27590.12 46.19 38575.49 122.32 38453.17 PASS 1500.001. 1432.75 7333 -301.18 1208.10 1356.69 26769.26 27587.68 46.25 38606.43 122.68 38483.75 PASS 1600.001 1510.88 8833 -361.79 1273.01 142137 26771.00 27586.21 46.33 38640.18 123.16 38517.02 PASS 1700.001' 1584.84 10429 -427.15 1334.54 1483.06 26772.61 27584.88 46.41 38676.66 123.79 38552.87 PASS 1800.001. 1654.34 12133 -496.97 1392.42 1540.91 26774.10 27583.69 46.49 38715.71 124.61 38591.11 PASS 1888.30 1711.77 13724 -562.12 1480.57 1629.02 26776.28 27581.94 46.57 38752.20 125.54 38626.66 PASS 1900.00} 1719.12 139.40 -570.96 1492.84 164128 26776.57 27581.69 46.58 38757.16 125.68 38631.48 PASS 2000.001 1781.99 157.84 -64631 1597.66 1746.05 26778.99 27579.62 46.68 38799.50 126.96 3867235 PASS 2013.00 1790.16 16024 -65633 1607.62 1756.01 26779.21 27579.42 46.69 38805.01 127.03 38677.99 PASS 2100.001. 1846.57 175.66 -720.74 1671.07 1819.43 26780.63 27578.16 46.77 38841.38 128.11 3871327 PASS 2200.001 1915.50 191.80 -79134 1748.47 1896.79 26782.39 27576.57 46.85 38881.85 129.47 3875239 PASS 2300.001 1988.58 206.19 -858.05 1831.76 1980.04 26784.32 27574.81 46.93 38920.74 130.76 38789.98 PASS 2400.001' 2065.55 218.77 -920.61 1921.83 2070.06 26786.45 27572.82 47,00 38957.89 131.99 38825.90 PASS 2410.70 2074.00 220.01 -927.05 1931.72 2079.95 26786.68 27572.60 47.01 38961.75 132.11 38829.64 PASS €1 27 • • cea Clearance Report VPII Olson 2r BAKER _ Cook Inlet Energy Closest Approach Page 16 of 25 HUGHES REFERENCE WELLPATH IDENTIFICATI• ° Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek CLEARANCE DATA-offset wellbore:Otter#1A Offset WeBpath:NavITrak MWD<4436-7021'> Facility:Otter Slot Otter#1 Welt Otter#1 Threshold Value=0.00 ft t=interpolated/extrapolated station Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Horiz C-C ACR Ellipse ACR [ft] fit] [ft] [R] Eft] [ft] [It] [R] Bearing Clear Dist MASD Sep Status [°] [R] IIt] [ft] 2420.90 2082.06 221.19 -933.19 1941.15 2089.37 26786.91 27572.39 47.02 38965.44 132.23 38833.21 PASS 2500.00} 2144.45 23032 -980.95 2006.99 2155.17 2678831 27570.88 47.07 38994.15 133.17 38860.98 PASS 2600.00} 2223.33 241.87 -104132 2052.58 2200.73 26789.69 27569.78 47.14 39030.53 134.39 38896.14 PASS 2700.00} 2302.21 253.42 -1101.70 2098.27' 2246.40 26791.00 27568.63 47.21 39067.04 135.65 38931.39 PASS, 2800.00} 2381.08 264.97 -1162.07 2144.07 2292.16 26792.44 27567.42 47.28 39103.68 136.96 38966.73 PASS 2900.001. 2459.96 276.52 -1222.45 2189.98 2338.02 26793.99 27566.15 47.35 39140.45 138.30 39002.15 PASS 3000.00} 2538.83 288.07 -1282.82 2234.04 2382.04 26795.60 27564.89 47.42 39177.34 139.67 39037.67 PASS 3100.00} 2617.71 299.62 -1343.20 2277.64 2425.59 26797.29 27563.60 47.49 39214.36 141.08 39073.28 PASS 3200.001. 269639 311.17 -1403.57 2321.32 2469.20 26799.08 27562.27 47.56 39251.51 142.53 39108.99 PASS 3300.001- 277 ! 322.72 -1463.95 2365.06 2512.89 680099 27560.90 47.63 39288.79 144.00 39144.80 PASS 3400.001. 2854.34 334.27 -152432 2423.12 2570.86 26803.66 27559.03 47.69 39326.20 145.51 39180.70 PASS 3500.001. 2933.22 345.82 -1584.70 2512.73 2660.30 26808.04 27555.88 47.76 39363.64 147.06 39216.58 PASS 3600.00} 3012.09 35737 -1645.07 2551.50 2699.00 26810.02 27554.48 47.83 39401.19 148.61 39252.58 PASS 3700.001. 3090.97 368.92 -1705.45 2590.27 2737.69 26812.05 27553.08 47.89 39438.88 150.18 39288.69 PASS 3800.00} 3169.84 380.47 -1765.82 2614.20 2761.56 2681334 27552.21 47.96 39476.71 151.77 39324.94 PASS 3900.00} 3248.72 392.02 -182620 2633.16 2780.48 26814.41 27551.54 48.03 39514.72 153.37 39361.35 PASS 4000.00} 3327.60 40337 -188637 2652.11 2799.39 2681551 27550.86 48.10 39552.90 154.99 39397.92 PASS 4100.00} 3406.47 415.12 -194695 2671.07 2818.301 26816.66 27550.19 48.17 39591.27 156.62 39434.65 PASS 4200.00} 3485.35 426.67 -200732 2690.03 2837.21 26817.85 27549.53 48.24 39629.81 158.27 39471.54 PASS 4300.00} 3564.23 43822 -2067.70 2705.48 2852.62 26818.85 27548.99 48.31 39668.52 159.94 39508.59 PASS 4400.00} 3643.10 449.77 -2128.07 2717.03 2864.14 26819.62 27548.59 48.38 39707.43 161.61 39545.82 PASS 4500.00} 3721.98 46132 -2188.45 2728.58 2875.65 26820.41 27548.20 48.45 39746.53 163.30 39583.23 PASS 4600.00} 3800.85 472.87 -2248.82 2740.12 2887.16 26821.23 27547.82 48.52 39785.81 165.00 39620.81 PASS 4700.00} 3879.73 484.42 -2309.20 2751.66 2898.66 26822.08 27547.44 48.58 39825.28 166.71 39658.58 PASS 4800.00} 3958.61 495.97 -236957 2763.19 2910.15 26822.94 27547.07 48.65 39864.94 168.43 39696.52 PASS l 4900.001- 4037.48 50732 -242995 2774.72 2921.64 26823.83 27546.70 48.72 39904.79 170.16 39734.64 PASS 5000.00} 4116.36 519.07 -249032 2786.24 2933.12 26824.74 27546.34 48.79 39944.83 171.89 39772.93 PASS 5100.00} 4195.24 530.62 -2550.70 2797.76 2944.59 26825.68 27545.98 48.86 39985.05 173.64 39811.41 PASS 5200.00} 4274.11 542.17 -2611.07 2811.91 2958.69 26826.86 27545.55 48.92 40025.46 175.40 39850.06 PASS E 5300.00} 4352.99 553.72 -2671.45 2826.69 2973.41 26828.12 27545.11 48.99 40066.04 177.16 39888.88 PASS E €a 28 • • ceB Clearance Report FARE Olson 2`'erg BAKER Cook Inlet Energy CbsestApproach Page 17 of 25 HUGHES ` ';NCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek CLEARANCE DATA-offset Wellbore:Otter#IA Offset Wdlpatb:NavlTrak MWD<4436-7021'> Facility:Otter Slot Otter#1 Welt Otter#1 Threshold Vaine=0.00 ft t=Inte[polatediextrapolated station Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Horiz C-C ACR Ellipse ACR [ft] lit] [ft] [R] St] [fti [It] [ft] Bearing Clear Dist MASD Sep Status [9 [R] 8t1 lit] i 5400.00} 4431.86 565.27 -2731.82 2841.47 2988.13 26829.42 27544.68 49.06 40106.81 178.93 39927.87 PASS 5500.00} 4510.74 576.82 -2792.20 2856.24 3002.84 26830.74 27544.25 49.13 40147.75 180.71 39967.04{PASS 5600.00} 4589.62 58837 -285237 2871.01 3017.54 26832.09 27543.82 49.19 40188.87 182.49 40006.37 PASS 5700.00}{ 4668.49 599.92 -2912.95 2885.77 3032.22 26833.47 27543.41 49.26 40230.16 184.28 40045.88 PASS 5800.00} 4747.37 611.47 -297332 2900.52 3046.90 26834.88 27543.00 49.33 40271.63 186.07 40085.56 PASS 5900.00} 4826.25 623.02 -3033.70 2915.17 3061.48 2683631 27542.60 49.39 40313.28 187.87 40125.41 PASS 6000.00} 4905.12 63457 -3094.07 2929.81 3076.04 26837.76 27542.21 49.46 40355.10 189.67 40165.43 PASS 6100.00} 4984.00 646.12 -3154.45 2944.44 3090.59 2683923 27541.84 49.53 40397.10 191.47 40205.63 PASS 6200.00} 5062.87 657.67 -3214.82 2959.05 3105.11 26840.72 27541.48 49.59 40439.27 193.28 40245.99 PASS 6300.00} 5141.75 66922 -327520 2973.64 3119.62 26842.24 27541.13 49.66 40481.62 195.09 40286.53 PASS 6400.00} 5220.63 680.77 -333557 2988.22 3134.12 26843.78 27540.79 49.72 40524.14 196.90 40327.24 PASS 6500.00} 5299.50 69232 -3395.95 3003.16 3148.97 2684538 27540.45 49.79 40566.83 198.71 40368.12 PASS 6600.00} 5378.38 703.87 -345632 3019.72 3165.43 26847.18 27540.09 49.86 40609.69 200.53 40409.16 PASS 6700.00} 5457.25 715.42 -3516.70 3036.27 3181.87 26849.01 27539.73 49.92 40652.72 202.35 40450.37 PASS 6800.00} 5536.13 726.97 -3577.07 3052.80 3198.29 26850.87 27539.39 49.99 40695.92 204.17 40491.75 PASS 6900.00} 5615.01 73852 -3637.44 3069.32 3214.70 26852.77 27539.05 50.05 40739.28 206.00 40533.29 PASS 7000.00} 5693.88 750.07 -3697.82 3085.83 3231.10 26854.68 27538.72 50.11 40782.81 207.82 40574.99 PASS 7100.00} 5772.76 761.62 -3758.19 3101.91 3247.06 2685658 27538.41 50.18 40826.51 209.64 40616.87 PASS 7200.00} 5851.64 773.17 -381857 3115.41 3260.46 26858.20 27538.16 50.24 40870.37 211.46 40658.91 PASS, 7300.00} 5930.51 784.72 -3878.94 3128.90 3273.85 26859.84 27537.91 50.31 40914.41 213.28 40701.12 PASS',' 7400.001- 6009.39 796.27 -393932 3142.38 3287.22 2686150 27537.68 50.37 40958.61 215.10 40743.51 PASS I 7446.50 6046.07 801.64 -396739 3148.64 3293.43 2686228 27537.58 50.40 40979.23 215.95 40763.28 PASS 7500.00} 6088.72 807.69 -3999.11 3155.91 3300.64 26863.19 27537.46 50.44 41002.65 216.90 40785.76 PASS 7600.00} 6170.80 81831 -4055.22 3169.85 3314.47 26864.95 27537.24 50.50 41044.72 218.44 40826.28 PASS 7700.00} 6255.76 828.01 -4107.05 3184.22 3328.73 26866.79 27537.02 50.55 41084.47 219.90 40864.57 PASS, 7777.90 6323.78 834.90 -414437 3195.69 3340.10 26868.28 27536.86 50.59 41113.74 220.91 40892.83 PASS 7800.00/. 6343.29 836.77 -415457 3198.9& 3343.35 26868.71 27536.82 50.60 41121.84 221.18 40900.65 PASS l 7900.001- 6431.60 845.24 -4200.73 3212.94 3357.19 2687055 27536.63 50.65 41158.58 222.42 40936.17 PASS 8000.00} 6519.90 853.72 -4246.89 3226.82 3370.95 26872.41 27536.46 50.70 41195.50 223.65 40971.86 PASS 8100.00} 6608.20 862.19 -4293.05 3240.69 3384.69 26874.29 2753630 50.74 41232.61 224.88 41007.73 PASS €1 29 I • ceB Clearance Report Irfiii■ Olson 2r BAKER Cook Inlet Energy_ Closest Approach Page 18 of 25 HUGHES ERE NC E Vs ELLPATH IDENTIFICATION Operator'Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek CLEARANCE DATA-Offset Wellbore:Otter#1A Offset Wdlpelh:Nat/Trek MWD<4436-7021'> Facility:Otter Slot Otter#1 Welt Otter#1 Threshold Vakie=0.00 ft ?=interpolated/extrapolated station Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Hark C-C ACR Ellipse ACR [ft] [R] [rt] [It] let] 8t] [rt] Rt] Bearing Clear Dist MASD Sep Status P] Iftl Ift] Ft] 8200.00} 6696.51 870.66 -4339.21 3254.54 3398.41 26876.19 27536.15 50.79 41269.89 226.11 41043.78 PASS 8300.00} 6784.81 879.13 -4385.37 3268.38 3412.11 26878.12 27536 50.84 41307.35 22734 41080.01 PASS 8400.00} 6873.11 887.60 -4431.53 3282.20 3425.79 26880.07 27535.89! 50.89 41344.99 228.57 41116.42 PASS 8500.00} 6961.41 896.08 -4477.69 3296.01 3439.45 26882.04 27535.77 50.93 41382.80 229.80 41153.01 PASS 8600.00} 7049.72 90455 -4523.86 7006.35 7134.37 2708658 2756591 50.79 41415.69 234.27 41181.42 PASS 8700.00} 7138.02 913.02 -4570.02 7021.00 7149.02 2708630 27566.10 50.84 41446.00 235.53 41210.47 PASS 8800.00} 7226.32 921.49 -4616.18 7021.00 7149.02 2708630 27566.10 50.89 41476.53 236.79 41239.74 PASS 8900.00} 7314.63 929.96 -4662.34 7021.00 7149.02 2708630 27566.10 50.94 41507.27 238.04 41269.23 PASS 9000.00} 7402.93 938.44 -4708.50 7021.00 7149.02 2708630 27566.10 50.99 41538.24 239.29 41298.95 PASS 9100.00} 7491.23 946.91 -4754.66 7021.00 7149.02 2708630 2756610 51.04 41569.42 24034 41328.88 PASS 9200.00} 7579.54 955.38 -4800.82 7021.00 7149.02 2708630 27566.10 51.09 41600.82 241.79 41359.03 PASS 9300.00} 7667.84 963.85 -4846.98 7021.00 7149.02 2708630 27566.10 51.13 41632.43 243.04 4138939 PASS 9400.00} 7756.14 97232 -4893.14 7021.00 7149.02 2708630 27566.10 51.18 41664.26 244.28 4141998 PASS 9500.00} 7844.44 980.80 -4939.30 7021.00 7149.02 2708630 27566.10 51.23 41696.31 24533 41450.78 PASS 9600.00} 7932.75 989.27 -4985.46 7021.00 7149.02 2708630 27566.10 51.28 41728.57 246.77 41481.80 PASS 9700.00} 8021.05 997.74 -5031.62 7021.00 7149.02 2708630 27566.10 51.33 41761.05 248.01 41513.04 PASS 9800.00} 8109.35 1006.21 -5077.78 7021.00 7149.02 2708630 27566.10 51.38 41793.74 249.25 41544.49 PASS 9900.00} 8197.66 1014.68 -5123.95 7021.00 7149.02 2708630 27566.10 51.43 41826.64 250.49 41576.15 PASS 10000.00} 8285.96 1023.16 -5170.11 7021.00 7149.02 2708630 27566.10 51.48 41859.76 251.73 41608.03 PASS 10100.00} 8374.26 1031.63 -5216.27 7021.00 7149.02 2708630 27566.10 51.52 41893.09 25296 41640.13 PASS 10200.00} 8462.56 1040.10 -5262.43 7021.00 7149.02 2708630 27566.10 51.57 41926.63 254.19 41672.44 PASS 10300.00} 8550.87 104837 -5308.59 7021.00 7149.02 2708630 27566.10 51.62 41960.38 255.43 4170496 PASS 10400.00} 8639.17 1057.05 -5354.75 7021.00 7149.02 2708630 27566.10 51.67 41994.35 256.66 41737.69 PASS 10500.00} 8727.47 106532 -5400.91 7021.00 7149.02 2708630 27566.10 51.72 42028.52 257.88 41770.64 PASS 10600.00} 8815.78 1073.99 -5447.07 7021.00 7149.02 2708630 27566.10 51.76 42062.91 259.11 41803.80 PASS 10700.001- 8904.08 1082.46 -5493.23 7021.00 7149.02 2708630 27566.10 51.81 42097.50 26033 41837.17 PASS 10800.00} 8992.38 109093 -55_39.39 7021.00 7149.02 2708630 27566.1 0 51.86 42132.30 26155 41870.75!PASS 10900.001- 9080.69 1099.41 -555.55 7021.00 7149.02 2708630 27566.10 51.91 42167.31 262.77 41904.54 PASS 11000.00} 9168.99 1107.88 -5631.71 7021.00 7149.02 2708630 27566.10 51.96 42202.53 26399 41938.54 PASS 11100.00} 9257.29 111635 -5677.87 7021.00 7149.02 2708630 27566.10 52.00 42237.96 265.21 41972.75 PASS €9 30 • • cell Clearance Report Wait' Cook Inlet EnergyOlson2 rBAKER - Cbsestest Approach Page 19 of 25 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well - Olson 2 Field Olson Creek Unit Wellbore Olson 2 WeUUPlan Facility Olson Creek CLEARANCE DATA-Offset Wellbore:otter#1A Offset Welipath:NeviTrak MWD<4436-7021'> Facility:Otter Slot:Otter#1 Welt Otter#1 Threshold Vaste=0.00 ft t=tnterpolated/extrapolated statim Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Hartz C-C ACR Ellipse ACR l t] Ertl [11 gy [ft] Rt] [rt] [n] Bearkig Clear Dist MASD Sep Status P] In] [ft] [It] 11200.00} 9345.59 1124.821 -5724.03 7021.00 7149.02 2708630 27566.10 52.05 42273.59 266.42 42007.171 PASS 11300.00} 9433.90 1133.29 -5770.20 7021.00 7149.02 2708630 27566.10 52.10 42309.43 267.63 42041.80 PASS 11400.00} 9522.20 1141.77 -5816.36 7021.00 7149.02 2708630 27566.10 52.15 42345.48 268.84 42076.64 PASS 11500.00} 9610.50 1150.24 -5862.52 7021.00 7149.02 2708630 27566.10 52.19 42381.73 270.05 42111.68 PASS 11600.00} 9698.81 1158.71 -5908.68 7021.00 7149.02 2708630 27566.10 52.24 42418.18 271.25 42146.93 PASS 11700.00} 9787.11 1167.18 -5954.84 7021.00 7149.02 2708630 27566.10 52.29 42454.84 272.46 42182.39 PASS 11800.00} 9875.41 1175.65 -6001.00 7021.00 7149.02 2708630 27566.10 52.34 42491.71 273.66 42218.05 PASS 11900.00} 9963.72 1184.13 -6047.16 7021.00 7149.02 2708630 27566.10 52.38 42528.77 274.86 42253.92 PASS L 11967.90 10023.67 1189.88 -6078.50 7021.00 7149.02 2708630 27566.10 52.41 42554.06 275.67 42278.39 PASS POSITIONAL UNCERTAINTY- Offset Wellbore:Otter#1A Offset Wellpath:Nav4TrakMWD<4436-7021'> Slot Surface Uncertainty @1SD Horizontal 2.000ft Vertical 1.000ft yacility Surface Uncertainty @1SD Horizontal 20.000ft Vertical 3.000ft WELLPATH COMPOSITION-Offset Wellbore:Otter#IA Offset Wellpath:NaviTrakMWD<4436-7021'> Start MD End MD Positional Uncertnty Model L og Name/Comment Wellbore [ft] [ft] 0.00 4400.00 Genetic gyro-continuous(Drillpipe) Otter#1 OMS(200-5686) Otter#1 4400.00 7021.00 Naviltak(Standard) NaviTrak MWD<4436-7021'> Otter#1A OFFSET WELLPATH MD REFERENCE- Offset Weilbore:Otter#1A Offset Wellpath:NaviTrak MWD<4436-7021'> MD Reference:Miller Rig#34(RTE) Offset TVD&local coordinates use Reference Wellpath settings (See WELLPATH DATUM on page 1 of this report) Ellipse Start MD 324.40ft 31 • • ¢a Clearance Report ValiII Olson 2 Ver#4 BAKER _ Cook Inlet Energy Closest Approach Page 20 of 25 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan 'Facility Olson Creek CLEARANCE DATA-Offset Wellbore:Otter#1 Offset Wellpath:Otter#1<0-5686> Facility:Otter Slot Otter#1 Welt Otter#1 Threshold Value=0.00 ft t=lnterpolated/e¢trapolated station Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North OlfsetEast Hork C-C ACR Ellipse ACR gt] pt] 1111 pt] VO [It] ]ft] [ft] Bearing Clear Dist MASD Sep Status [1 [ft] RI [tt] 0.00 0.00 0.00 0.00 0.00 149.15 26741.81 27608.57 45.91 38436.70 1.01 38435.69 PASS 100.00t 100.00 0.00 0.00 0.00 149.15 26741.81 27608.57 45.91 38436.44 1.01 38435.43 PASS 160.001. 160.00 0.00 0.00 10.00 159.15 26741.81 27608.56 45.91 38436.41 1.01 38435.40 PASS 200.001. 200.00 0.00 0.00 31.90 181.05 26741.85 27608.54 45.91 38436.42 1.01 38435.41'PASS 300.001 300.00 0.00 0.00 94.63 243.78 26742.14 27608.34 45.91 38436.52 0.85 38435.67 PASS 400.001. 400.00 0.00 0.00 157.35 306.49 26742.74 27607.93 45.91 38436.71 60.99 38375.72 PASS 500.00 500.00 0.00 0.00 229.59 378.73 26743.77 27607.23 45.91 38437.00 60.99 38376.01 PASS 600.001. 599.93 0.76 -3.12 322.09 471.20 26745.45 27606.02 45.91 38439.03 61.00 38378.03 PASS 684.431. 684.00 259 -1059 400.00 549.08 26747.14 27604.75 45.92 38443.42 121.33 38322.09 PASS 700.001. 699.45 3.04 -12.45 412.14 561.22 26747.43 27604.53 45.92 38444.50 121.33 38323.16 PASS 800.001. 798.15 6.83 -27.97 489.79 638.83 26749.33 27603.11 45.94 3845339 121.37 38332.02 PASS 900.001. 895.62 12.11 -49.60 566.62 715.62 26751.36 27601.62 45.96 38465.70 121.42 3834427;PASS 1000.001. 991.46 18.86 -77.27 660.65 809.591 26753.98 27599.71 45.99 38481.36 121.50 38359.861 PASS 1100.001. 1085.28 27.06 -110.85 767.06 915.94 26756.99 27597.49 46.03 38500.25 121.60 38378.65 PASS 1200.001. 1176.69 36.67 -150.20 877.67 1026.48 26760.12 27595.11 46.08 38522.30 121.74 3840036 PASS 1300.001. 1265.31 47.65 -195.17 988.18 1136.92 26763.21 27592.68 46.13 38547.41 121.94 3842.5.47 PASS 1400.001 1350.78 5995 -24556 1102.42 1251.08 26766.37 27590.12 46.19 38575.49 122.21 38453.28 PASS 1500.001. 1432.75 7353 -301.18 1208.10 1356.69 26769.26 27587.68 46.25 38606.43 122.57 38483.86 PASS 1600.001. 1510.88 8833 -361.79 1273.01 142157 26771.00 27586.21 46.33 38640.18 123.05 38517.13 PASS 1700.001. 1584.84 10429 -427.15 1334.54 1483.06 26772.61 27584.88 46.41 38676.66 123.68 38552.98 PASS 1800.001- 1654.34 12133 -496.97 1392.42 1540.91 26774.10 27583.69 46.49 38715.71 124.50 38591.22 PASS 1888.30 1711.77 13724 -562.12 1480.57 1629.02 26776.28 27581.94 46.57 38752.20 125.43 38626.77 PASS 1900.001. 1719.12 139.40 -570.96 1492.84 164128 26776.57 27581.69 46.58 38757.16 125.57 3863158 PASS 2000.001 1781.99 157.84 -64651 1597.66 1746.05 26778.99 27579.62 46.68 38799.50 126.85 38672,65 PASS 2013.00 1790.16 16024 -65633 1607.62 1756.01 26779.21 27579.42 46.69 38805.01 126.92 38678.09 PASS 2100.001 1846.57 175.66 -720.74 1671.07 1819.43 26780.63 27578.16 46.771 38841.38 128.11 3871327.PASS . 2200.001 1915.50 191.80 -79134 1748.47 1896.79 26782.39 27576.57 46.85! 38881.85 129.47 38752391 PASS 2300.001 1988.58 206.19 -858.05 1831.76 1980.04 26784.32 27574.81 46.93 38920.74 130.76 3878998 PASS 2400.001 2065.55 218.77 -920.61 1921.83 2070.06 26786.45 27572.82 47.00 38957.89 131.99 38825.90 PASS 2410.70 2074.00 220.01 -927.05 1931.72 207995 26786.68 27572.60 47.01 38961.75 132.11 38829.64 PASS €8 32 0 • aeB Clearance Report FA`. Cook Inlet EnergyOlson 2 rBAKER Closest Approach Page 21 of 25 NVesliES REFERENCE WELLPATH IDENTIFICATION ..___] Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek CLEARANCE DATA-Offset Wellbore:Otter#1 Offset Welipath:Otter#1<0-5686> Facility:Otter Slot Otter#1 Welk Otter#1 Threshold Vakte=0.00 ft 5=interpolatedle trapolated station Ref MD Ref TVD Ref North Ref East Offset MD Off set TVD Offset North Off set East Hartz C-C ACR Ellipse ACR [ft] St] Ft] Ft] Eft] [ft] Fit] [h] Bearing Clear Dist MASD Sep Status [1 [al Ftl Irt] 2420.90 2082.06 221.19 -933.19 1941.15 2089.37 26786.91 27572.39 47.02 38965.44 132.23, 38833.21 PASS 2500.00} 2144.45 23032 -980.95 2006.99 2155.17 2678831 27570.88 47.07: 38994.15 13_3.17 38860.98 PASS 2600.00} 2223.33 241.87 -104132 2052.58 2200.73 26789.69 27569.78 47.14 39030.53 134.39 38896.14 PASS 2700.00} 2302.21 253.42 -1101.70 2098.27 2246.40 26791.00 27568.63 47.21 39067.04 135.55 38931.49 PASS 2800.00} 2381.08 26497 -1162.07 2144.07 2292.16 26792.44 27567.42 47.28 39103.68 136.85 38966.83 PASS 2900.00} 2459.96 27632 -1222.45 2189.98 2338.02 26793.99 27566.15 47.35 39140.45 138.19 39002.25 PASS 3000.00} 2538.83 288.07 -1282.82 2234.04 2382.04 26795.60 27564.89 47.42 39177.34 139.57 39037.77 PASS 3100.00} 2617.71 299.62 -1343.20 2277.64 2425.59 26797.29 27563.60 47.49 39214.36 140.98` 39073.38 PASS 3200.00} 2696.59 311.17 -140337 2321.32 2469.20 26799.08 27562.27 47.56 39251.51 142.42 39109.09 PASS 3300.00} 2775.46 322.72 -1463.95 2365.06 2512.89 26800.99 27560.90 47.63 39288.79 143.89 39144.90 PASS I 3400.00} 2854.34 334.27 -152432 2423.12 2570.86 26803.66 27559.03 47.69 39326.20 145.40 39180.80 PASS 3500.00} 2933.22 345.82 -1584.70 2512.73 2660.30 26808.04 27555.88 47.76 39363.64 146.96 39216.69 PASS 3600.00} 3012.09 35737 -1645.07 2551.50 2699.00 26810.02 27554.48 47.83 39401.19 148.51 392.52.68 PASS 3700.00} 3090.97 368.92 -1705.45 2590.27 2737.69 26812.05 27553.08 47.89 39438.88 150.08 39288.80 PASS 3800.00} 3169.84 380.47 -1765.82 2614.20 2761.56 2681334 27552.21 47.96 39476.71 151.66 39325.05 PASS 3900.00} 3248.72 392.02 -1826.20 2633.16 2780.48 26814.41 27551.54 48.03 39514.72 153.26 39361.46 PASS 4000.00} 3327.60 40337 -188657 2652.11 2799.39 2681531 27550.86 48.10 39552.90 154.88 39398.02 PASS 4100.00} 3406.47 415.12 -1946.95 2671.07 2818.30 26816.66 27550.19 48.17 39591.27 156.52 39434.75 PASS 4200.00} 3485.35 426.67 -200732 2690.03 2837.21 26817.85 27549.53 48.24 39629.81 158.17 39471.64 PASS 4300.00} 3564.23 43822 -2067.70 2705.48 2852.62 26818.85 27548.99 48.31 39668.52 159.83 39508.69 PASS` 4400.00} 3643.10 449.77 -2128.07 2717.03 2864.14 26819.62 27548.59 48.38; 39707.43 161.51 39545.92 PASS 4500.00} 3721.98 46132 -2188.45 2728.58 2875.65 26820.41 27548.20 48.45' 39746.53 163.191 39583.33 PASS 4600.00} 3800.85 472.87 -2248.82 2740.12 2887.16, 2682123 27547.82 48.52 39785.81 164.89 39620.92 PASS 4700.00} 3879.73 484.42 -230920 2751.66 2898.66 26822.08 27547.44 48.58 39825.28 166.60 39658.68 PASS 4800.00} 3958.61 495.97 -2369.57 2763.19 2910.15 26822.94 27547.07 48.65 39864.94 168.32 39696.62 PASS 4900.00} 4037.48 50752 -242995 2774.72 2921.64 26823.83 27546.70 48.72 39904.79 170.05 39734.74 PASS 5000.00} 4116.36 519.07 -249032 2786.24 2933.12 26824.74 27546.34 48.79 39944.83 171.79 39773.04 PASS 5100.00} 4195.24 530.62 -2550.70 2797.76 2944.59 26825.68 27545.98 48.86 39985.05 173.54 39811.51 PASS 5200.00} 4274.11 542.17 -2611.07 2811.91 2958.69 26826.86 27545.55 48.92 40025.46 175.29 39850.16`PASS 5300.00} 4352.99 553.72 -2671.45 2826.69 2973.41 26828.12 27545.11 48.99 40066.04 177.06 39888.98 PASS €1 33 • • Clearance Report iI Olson 2r BAICER _ Cook Inlet Energy_ Closest Approach Page 22 of 25 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek CLEARANCE DATA-Offset Wellbore:Otter#1 Offset Wdlpath:Otter#1<0-5686> Facility:Otter Slot Otter#1 Welt Otter#1 Threshold Vahe=0.00ft t=interpolated/extrapolated station Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Horh C-C ACR Ellipse ACR [ft] [ft] @'t] [R] Qt] pt] pt] [R] Bearing Clear Dist MASD Sep Status [y [R] [it] [ft] 5400.001- 4431.86 565.27 -2731.82 2841.47 2988.13 26829.42 27544.68 49.06 40106.81 178.83 39927.98 PASS 5500.001. 4510.74 576.82 -2792.20 2856.24 3002.84 26830.74 27544.25 49.13 40147.75 180.61 39967.14 PASS 5600.00} 4589.62 58837 -285257 2871.01 3017.54 26832.09 27543.82 49.19 40188.87 182.39 40006.48 PASS 5700.001. 4668.49 599.92 -2912.95 2885.77 3032.22 26833.47 27543.41 49.26 40230.16 184.18 40045.99 PASS 5800.001. 4747.37 611.47 -297332 2900.52 3046.90 26834.88 27543.00 49.33 40271.63 185.97 40085.66 PASS 5900.001. 4826.25 623.02 -3033.70 2915.17 3061.48 26836.31 27542.60 49.39 40313.28 187.77 40125.52 PASS 6000.001. 4905.12 63457 -3094.07 2929.81 3076.04 26837.76 27542.21 49.46 40355.10 189.57 40165.54 PASS 6100.001. 4984.00 646.12 -3154.45 2944.44 3090.59 26839.23 27541.84 49.53 40397.10 191.37 40205.73 PASS 6200.001. 5062.87 657.67 -3214.82 2959.05 3105.11 26840.72 27541.48 49.59 40439.27 193.18 40246.10 PASS 6300.001. 5141.75 66922 -327520 2973.64 3119.62 26842.24 27541.13 49.66 40481.62 194.98 40286.64 PASS 6400.001. 5220.63 680.77 -333557 2988.22 3134.12 26843.78 27540.79 49.72 40524.14 196.80 40327.34 PASS 6500.001. 5299.50 69232 -3395.95 3003.16 3148.97, 26845.38 27540.45 49.79 40566.83 198.61 40368.22 PASS 6600.001. 5378.38 703.87 -345632 3019.72 3165.43! 26847.18 27540.09 49.86 40609.69 200.43 40409.26 PASS 6700.001. 5457.25 715.42 -3516.70 3036.27 3181.87 26849.01 27539.73 49.92 40652.72 202.25 40450.47 PASS 6800.001. 5536.13 726.97 -3577.07 3052.80 3198.29 26850.87 27539.39 49.99 40695.92 204.07 40491.85 PASS 6900.001. 5615.01 73852 -3637.44 3069.32 3214.70 26852.77 27539.05 50.05 40739.28 205.89 40533.39 PASS 7000.001. 5693.88 750.07 -3697.82 3085.83 3231.10 26854.68 27538.72 50.11 40782.81 207.71 40575.10 PASS 7100.00f 5772.76 761.62 -3758.19 3101.91 3247.06 2685658 27538.41 50.18 40826.51 209.54 40616.97 PASS 7200.001. 5851.64 773.17 -381857 3115.41 3260.46 26858.20 27538.16 50.24 40870.37 211.36 40659.01 PASS 7300.001. 5930.51 784.72 -3878.94 3128.90 3273.85 26859.84 27537.91 50.31 40914.41 213.18 40701.23 PASS 7400.00f 6009.39 796.27 -393932 3142.38 3287.22 26861.50 27537.68 50.37 40958.61 215.00 40743.61 PASS 7446.50 6046.07 801.64 -396739 3148.64 3293.43 26862.28 27537.58 50.40 40979.23 215.85 40763.38 PASS 7500.001. 6088.72 807.69 -3999.11 3155.91 3300.64 26863.19 27537.46 50.44 41002.65 216.79 40785.86 PASS 7600.001. 6170.80 81831 -405522 3169.85 3314.47 26864.95 27537.24 50.50 41044.72 218.34 40826.39 PASS 7700.001 6255.76 828.01 -4107.05 3184.22 3328.73 26866.79 27537.02 50.55 41084.47 219.79 40864.67 PASS 7777.90 6323.78 834.90 -414437 3195.69 3340.10 26868.28 27536.86, 50.59 41113.74 220.81 40892.94 PASS 7800.001- 6343.29 836.77 -4154_57 3198.98 3343.35 26868.71 27536.821 50.60 41121.84 221.08 40900.76 PASS 7900.001- 6431.60 845.24. -4200.73 3212.94 3357.19 26870.55 27536.63 50.65 41158.58 222.31 40936.27,PASS 8000.001- 6519.90 853.72 -4246.89 3226.82 3370.95 26872.41 27536.46 50.70 41195.50 223.54 40971.96'PASS 8100.001. 6608.20 862.19 -4293.05 3240.69 3384.69 26874.29 27536.30 50.74 41232.61 224.77 41007.83 PASS 34 r • • ceB Clearance Report FAIIIII Cook Inlet EnergyOlson 2 ra BAKER Closest Approach Page 23 of 25 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot Olson 2 Slat Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek CLEARANCE DATA-Offset Wellborn:Otter#1 Offset Wdlpath:Otter#1<0-5686> Facility:Otter Slot Otter#1 Welt Otter#1 Threshold Vahe=0.00 ft f=Interpolated/extrapolated station Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Rork C-C ACR Ellipse ACR [RI [R] [R] [ft] Ifti [R] [R] [ft] Bearing Clear Dist MASD Sep Status P] [ft] IR] Rti] 8200.00} 6696.51 870.66 -4339.21 3254.54 3398.41 26876.19 27536.15 50.79 41269.89 226.00 41043.88 PASS 8300.00} 6784.81 879.13 -4385.37 3268.38 3412.11 26878.12 27536.01 50.84 41307.35 227.23 41080.11 PASS 8400.00} 6873.11 887.60 -4431.53 3282.20 3425.79 26880.07 27535.89 50.89 41344.99 228.46 41_11652 PASS 8500.00} 6961.41 896.08 -4477.69 3296.01 3439.45 26882.04 27535.77 50.93 41382.80 229.69 41153.11 PASS 8600.00} 7049.72 90435 -4523.86 3311.36 3454.65 2688426 27535.66 50.98 41420.80 230.92 41189.87 PASS: 8700.00} 7138.02 913.02 -4570.02 3327.33 3470.44 2688639 2753556 51.03 41458.96 232.15 41226.81 PASS 8800.00} 7226.32, 921.49 -4616.18 3343.28 3486.22 26888.95 27535.47 51.07 41497.30 233.38 41263.92 PASS 8900.00} 7314.63 929.96 -4662.34 3359.20 3501.96 2689132 27535.40 51.12 41535.80 234.61 41301.20 PASS 9000.00} 7402.93 938.44 -4708.50 3375.11 3517.69 26893.72 2753535 51.17 41574.48 235.84 41338.65 PASS 9100.00} 7491.23 946.91 -4754.66 3390.99 3533.38 16896.13 27535.32 51.21 41613.33 237.06 4137627 PASS 9200.00} 7579.54 95538 -4800.82 3407.67 3549.86 26898.69 2753530 51.26 41652.35 238.29 41414.06 PASS 9300.00} 7667.84 963.85 -4846.98 3425.39 3567.38 26901.44 27535.29 51.31 41691.54 23932 41452.02 PASS 9400.00} 7756.14 97232 -4893.14 3443.10 3584.86 26904.21 2753531 51.35 41730.89 240.74 41490.14 PASS 9500.00} 7844.44 980.80 -4939.30 3460.78 3602.32 26907.01 2753534 51.40 41770.40 241.97 41528.43 PASS 9600.00} 7932.75 98927 -4985.46 3478.43 3619.75 26909.82 27535.39 51.44 41810.08 243.19 41566.89 PASS 9700.00} 8021.05 997.74 -5031.62 3496.06 3637.15 26912.66 27535.45 51.49 41849.92 244.42 4160551 PASS 9800.00} 8109.35 1006.21 -5077.78 3555.38 3695.68 2692228 27535.72 51.53 41889.90 245.72 41644.17 PASS 9900.00} 8197.66 1014.68 -5123.95 3623.66 3763.05 2693336 27536.04 51.57 41929.92 247.04 41682.88 PASS 10000.00} 8285.96 1023.16 -5170.11 3686.97 3825.52 26943.64 27536.40 51.60 41970.02 24836 41721.66 PASS 10100.00} 8374.26 1031.63 -5216.27 3828.92 3965.63 26966.43 2753730 51.63 42010.07 249.83 41760.24 PASS 10200.00} 8462.56 1040.10 -5262.43 3891.38 4027.31 2697626 27537.84 51.67 42050.13 251.15 41798.98 PASS 10300.00} 8550.87 1048.57 -5308.59 4161.59 4294.42 27016.96 27540.77 51.67 42089.84 252.90 41836.94 PASS 10400.00} 8639.17 1057.05 -5354.75 4203.51 4335.86 27023.24 27541.20 51.71 42129.62 254.18 41875.45 PASS 10500.00} 8727.47 1 065 32 -5400.91 4271.83 4403.39 27033.55 27541.92 51.75 42169.49 255.51 41913.98 PASS 10600.00} 8815.78 1073.99 -5447.07 4335.52 4466.35 27043.19 2754260 51.79 42209.42 256.84 41952.58 PASS: 10700.00} 8904.08 1082.46 -5493.23, 4395.93 4526.05 2705239 27543.26 51.83 42249.42 258.16 4199126,PASS- 10800.00 t ASS10800.00} 8992.38 1090.93 -5539.391 4439.71 4569.32 27059.05 27543.78 51.87 42289.51 259.44 42030.07 PASS 10900.00} 9080.69 1099.41 -5585.55 4482.16 4611.28: 27065.47 2754438 51.91 42329.71 260.72 42068.99 PASS 11000.00} 9168.99 1107.88 -5631.71 4713.91 4840.39 27100.15 27547.66 51.93 42369.87 262.44, 42107.43 PASS 11100.00} 9257.29 111635 -5677.87 4751.29 4877.35 27105.75 27548.13 51.97 42409.90 263.71 42146.19 PASS €8 35 • • aeB Clearance Report IMO Cook Inlet EnergyOlson 2 r#4 B ER - Cbsest Approach Page 24 of 25 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) We II Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek CLEARANCE DATA-Offset Wellbore:Otter#1 Offset Wdlpath:Otter#1<8-5686> Facility:Otter Slot Otter#1 Well Otter#1 Threshold Vahe=0.00 ft t=interpolated/extrapolated station Ref MI) Ref TVD Ref North Ref East Offset MD Offset TVD Offset North OffsetEast Horiz C-C ACR Ellipse ACR lit] [ft] [R] pt] lit] [it] pt] [R] Bearing Clear Dist MASD Sep Status P] Rt] [ft] lit] 11200.00t 9345.59 1124.82 -5724.03 4788.64 4914.26 27111.42 27548.58 52.01 42450.05 26498 42185.07 PASS 11300.001 9433.90 1133.29 -5770.20 4869.58 4994.24 27123.79 27549.60 52.05 4249030 26636 42223.93 PASS 11400.001 9522.20 1141.77 -5816.36 4970.98 5094.47 27139.13 27550.97 52.08 4253033 267.79 42262.74 PASS 11500.001 9610.50 1150.24 -5862.52 5088.54 5210.67 27156.88 27552.51 52.11 42570.74 269.26 42301.48 PASS 11600.001 9698.81 1158.71 -5908.68 5133.74 5255.33 27163.78 27553.04 52.15 4261097 27036 42340.41 PASS 11700.001 9787.11 1167.18 -5954.84 5170.91 5292.05 2716958 27553.44 52.19 4265132 271.83 42379.49 PASS i 11800.00t 9875.41 1175.65 -6001.00 5204.65 5325.36 27174.93 27553.78 52.23 42691.79 273.09 42418.69 PASS ( 11900.00 9963.72 1184.13 -6047.16 5226.05 5346.48 2717838 27553.99 52.27 4273239 27433 42458.07 PASS 11967.90 10023.67 1189.88 -6078.50 5240.56 5360.80 27180.75 27554.13 52.30 42760.05 275.16 42484.89 PASS POSITIONAL UNCERTAINTY- Offset Wellbore:Otter#1 Offset Wellpath:Otter#1<0.5686> Slot Surface Uncertainty@1SD Horizontal 2.000ft Vertical 1.0008 iFacility Surface Uncertainty @1SD Horizontal 20.000ft Vertical 3.000ft HOLE&CASING SECTIONS-Offset wellbore:Otter#1 Offset Weupath:Otter#1<0-5686> ............ Siring/Diameter Start MD End MD Interval Start TVD End TVD Start N/S Start E/W End N/S End ENV [ft] [fe] [iil [n] [nl [nl [it] [ft] l>t] 10.75in Conducts 0.00 157.00 157.00 149.15 306.14 16301.71 16830.08 16301.99 16829.89 lin Casing 0.00 2092.00. 2092.00] 149.15 2240.13 16301.71 16830.08 16316.65 16817.96 4.5]n Casing 0.006 5686.001 5686.00 149.151 5798.951 16301.71 16830.08 16459.92 16814.22 €8 36 i oea Clearance Report FA.. Cook Inlet EnergyOlson 2 rBAKER — Closest Approach Page 25 of 25 HUGHES c N'RENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek WELLPATH COMPOSITION-Offset Wellbore Otter#1 Offset WeHpath:Otter#1<0-5686> Start MD End MD Positional Uncertainty Model Log Name/Comment Wellbore [ft] [ft] i 0.00 5686.00 Generic gyro-continuous(Drillpipe) Otter#1 GMS(200-5686) Otter#1 OFFSET WELLPATH MD REFERENCE- Offset Wellbore Otter#1 Offset Wellpath:Otter#1<0-5686> MD Reference:Miller Rig#34(RTE) Offset TVD&local coordinates use Retrence Wellpath settings (See WELLPATH DATUM on page 1 of this report) Ellipse Start MD 324.40ft €1 37 • 0 Olson Creek 2 Analysis Surface Location: 2593'FWL,2931' FNL, Sec 6, T13N, RlOW SM N 61 14'44.259",W 151 08' 11.361" (NAD 27 ASP Z4) N 2,648,980.00', E 299,832.00' Bottom Hole Loc: Estimated 1750' FWL, 1800' FNL, Sec 1, T13N, R11W SM 61 14'54.919" N, 151 10' 15.999" W (NAD 27 ASP Z4) N 2,650,170', E 293,754' Surface Elevation: —291.5 feet Estimated Drill Floor/KB: —17.4 feet/—308.9 feet Formation Tops (Estimated) Lower Sterling —200' and (Depths Estimated) Beluga —2,420" and/2,082' tvd (Depths Estimated) Upper Tyonek —7,820' and/6,345' tvd (Depths Estimated) Chickaloon —9,350' and/7,800' tvd (Depths Estimated) Well Description: Well is intended as a deviated grassroots exploration well to test the potential of the lower Beluga and Tyonek gas intervals. Primary completion is expected to be confined to the Beluga and Upper Tyonek intervals. Geology The Olsen Creek area is situated along the west/northwest flank of the Upper Cook Inlet Basin. The northeast trending structure appears to be set up along a northeast trending fault system, likely of transpressional origin, which is responsible for the development of the Three Mile Creek Field to the south-west of the Olson Creek prospect, as well as the Lone Creek Structure to the east of the Olson Creek prospect. This unnamed fault system is parallel and subordinate to the Bruin Bay Fault located further to the West/ Northwest of the location area, 38 • • and is generally considered the principal basin bounding fault in this portion of the basin. West of the Bruin Bay Fault, the Tertiary section of interest thins substantially. These sandstones were deposited in a variety of continental depositional systems, ranging from anastomozing stream channels and alluvial fan complexes, to axial meandering to braided fluvial environments. The provenance area is characterized by a magmatic arc; which contributed an immature quartz +feldspar+volcanic lithic assemblages. The formations expected at the Olson Creek Location are as follows: • Sterling Fm. (Late Miocene) If present, it may be very thin. Porosities range from 25%-30%, with permeabilities 100-500 md; The formation contains abundant volcanic rock fragments sourced from west; Mainly contains biogenic gas from interbedded coals; lower contact unconformable; Capped by glacial alluvium, so top seal can be an issue. • Beluga Fm. (Late Miocene) Porosities range from 17-24%, with permeabilities —50-400 md; Mainly claystones with thin interbedded sandstones, occasional gravels and lots of thin coals; usually contains biogenic gas from interbedded coals; Sands deposited in streams channels. • Tyonek Fm. (Early Oligocene — Late Miocene) Porosities range from 14-21, with permeabilities fro K— 40-100 md. Rocks were deposited in series of anastomozing stream channels with more and thicker coals than overlying Beluga Fm; Tyonek usually contains biogenic gas from coals. Geologic Hazards: Coals present in Tyonek Fms that tend to slough off and swell into the hole and are responsible for numerous stuck bits in previous wells. Coals are also present within the Beluga Fm although not as prevalent or as thick as in the Tyonek. Care should be exercised for sloughing coals, differential sticking and/or lost circulation when drilling the Tyonek Formation. Evaluation of surrounding wells and several seismic lines across the proposed location do not indicate any shallow gas hazards present and no abnormal pressures are 39 • anticipated. Drilling practices are posted for proper procedures on preventing and handling any gas kicks due to swabbing. Logging Services: Mud Logging services will be done by Canrig and commence after conductor pipe has been set(Gas detection to TD of well). 2 sets of dried and 1 wet samples will be collected every 30' to TD of well. Samples should be increased to every 10' if lithologies and gas detection warrant. 40 • • BOP & Diverter Sketch Operator: Cook Inlet EnerDate: 5-Sep-12 .%JJJJJJJJJJJJJJJJJJJJJ• lJJJJJJJJJJJJJJJJJJJJJv .i�i��:��:iii✓~i*f�i��i�ti � ��i�i� - \�i>>tii� �\i1i\)*i�i�irl �ity�$; 24' I 286" Bell Nipple Hydril"MSP" I16"Diverter Line with Hydraulic Actuated Full Opening Valve • la 1111111! 20" 12 1/4" 41 • • BOPE Schematic Operator: ('ll, Patters on III Rig No.191 Date: 4-Jun-13 NOW 11111111111111111•11111-111/------' I _ I Component Height" Annular 49.25 Double U 66.67 Drlg Spool +1-36" ______i._!____IPVII) Single U 41.69" Total: 193.61" Cameron D (T(p of 13 5/8"5M x 11.1M DS A=GL) 13-5/'10M Cameron U wwww, ' ' 1 1•'* 31/2"x5"VBR lei :;! 3-I/16",I0M Kill Line 1,y Blind Rams Fire Rated Hose s"--ks. AF" : :,di .=.1.1 Mud Cross has 4-1/16",10MOutI 13-5/8"10M • 4-1/16",10M,KillLine lli �Nal Fire Rated)lose 1'+ `/ a 1 ILII :=>_ j f-S/8'10M 3-1/16",10M GeteValves Cameron UI 4.1/16"HCR Gate Valve 3-1/16",10M x 4-1/16",10MDSA �--' Id.6 4-1/16",IOM Gate Valve .—� 3 1/2"x 5"VBR mamma_ 13-5/8"1014 I 5Mx 10M Et f i p , 11 C < i 2-1/16",5M,Gate Valve !! tit , 2-1/16",5m,Cate Valve k� , __ a 4 ki _ 42 0 ` • PATTERSON-UTI TYPE E - 10M Choke Manifold 1. _ Well Control � _ ' IIIII ' I 4:11-Z: �' , 0 (49 �' 0 (:),0'��r c •11 l / BO — — ffao - — , ` •w- % ) c ro __ oo - ` l — -- I iatTCSA strili.%.. IM;Om � ar).�.(fie _ .��., yr r�� !�� i�U v� •av v�� rdh — i : : 4 " 6 „,.0 0 0 0 Q, PM-334 e 4 1/16" 10M Manual Gate Valves 4 1/16" 10M Manual Choke Valves Valve® thru ,o TYPE Cameron. Valve® and 0 TYPE Cameron. 2 1/16" 10M Manual Gate Valve 3 1/16"10M Willis M-3 Remote Choke Valve® TYPE Cameron Valve® Type Cameron. 43 • i Wellhead Schematic ilt GE Oil &Gas 47.7. I. Mil oto • 2-WIT 9Y to 01)• CA 9dnr6Y ..... fh■IIro1IigT • i t� ,. ,:*: /.11 c7 zd^Ir OA 2-WIr BI ,tri.j 4W 1- 2-WIr GM A.w.(" "� 1241V l ` y. LW. I11.91 .S:1: d 17.4. Imu im 2/if la( 19.r �. aZ II*' :;- Y i I it.so , RI' 2- r mi r to r; to "I" Wiwi,. Ila ' rO 299itaY ( r — 24n6e114 } 2I'OD.lbw PW lith'Owing 7 Cep lie Cared lis V4•CreaLire 2-7/6.Tues. ALL DIMENSIONS ARE APPROXIMATE Tr.e&..1 p s 24.Pawrb of GE OI a O. Pra.rn.Coal*LP rias°onsider.d confident*une..Milano..nnlred in wing, COOK INLET ENERGY,LLC neater It nor b contents ery 9e used,copied,bsnwin9ed r n,pro2lwd except kr the sole puma..d GE 011 Ge.Proem Gonad Ir. OLSEN#2 9-5/8"x 7"x 2-7/8"5M SH2 Conventional Wellhead Assembly, DRAWN CR 09JUL14 APPWith T-M40-CCL Tubing Hanger and Adapter Flange RR FBRENCEONLYKN 09JUL14 DRAWING NO. 1001348 44 • GeoMechanical Plot- Calc Pore Olson Creek Proposed Geo Mechanical Plot Pressure Equivalent Mud Weight(PPG) 8 10 12 14 16 18 20 0 — terling+/-200' Mud 1 13 3/8" Weight 1000 (Pore Press. +Drilling 9 5 :" margin) 2000Frac Gradient Beluga +/-2410' MD+/-2074' D 3000 U- 4000 —_—__----- _.---_-_ ar 61 5000 6000 - 7000 7' 8000 Tyonek+/-77781tV1 D/- 6325'TVD 5 " 9000 45 • 0 Casing Program Cook Inlet Energy Casing Plan WELL NAME: Olson Creek 2 Well Information ENGINEER: Courtney Rust DATE: 17-Jun-14 Max EMW Estimated Hole Sizes Casing Size Estimated Range-Mud MD(ft) TVD(ft) (Pore Frac Grad at Mud Type Comments (in) (in) Pressure) Shoe (ppg) 13 3/8" — -- -- — — Conductor pipe 12 1/4" 95/8" 2,000 1,781 8.9 15.2 8.8 9.2 WBM Norm grad Based on offests 8 1/2" 7" 7,500 6,089 9.8 15.8 8.8 9.8 WBM 6 1/8" 5" 11,967 10,024 10.2 15.8 8.8 10,5 WBM Casing Plan 'ENTERYELLOW CELLS MANUALLY Connection API rating Casing Size • Wt lb/ftGrade MD ft ND ft (in) ( ) Type OD(in) Burst(psi) Collapse Tension ( ) ( ) (psi) (kips) 13 3/8" 68 L80 BTC -- -- -- — 0 0 95/8" 40 L80 BTC 10.625 6870 5750 1161 2000 1781 7" 26 L80 BTC 7.875 7240 5410 641 7500 6089 5" 18 L80 BTC 10140 10500 457 11967 10024 Variables&Formulas Wellhead 5,000 psi Gas Gradient 0.10 psi/ft Pore Pressure Gradient 0.460 psi MAWP=(0.80 X CASING BURST)or Limiting Wellhead Pressure MASP=Lessor of(Frac Pressure @(0.052 X(MW+0.5ppg SF)X ND)-GasGRD X ND))or (Max Pore Pressure-(GasGRD X ND)) MASCP=(0.80 X CASING BURST)-(MW-Backup FluidWt.)X.052 X ND SF Burst=Burst Value/MASP SF Collapse=Collapse Value/((0.052 X Max EMWPore Pressure X ND)-(gas gradient X TVD)) SF Tension=Tension Value/(Length X lb/ft) 46 • • Max Allowable Working Pressure MAWP=(0.80 X CASING BURST)or Limiting Wellhead Pressure Hole Sizes Casing Size' Safety Wellhead MD(ft) TVD(ft) Burst(psi) MAWP(psi) (in) (in) Factor (psi) 12 1/4" 9 5/8" 2,000 1,781 6870 0.8 5,000 5496 8 1/2" 7" 7,500 6,089 7240 0.8 5,000 5792 6 1/8" 5" 11,967 10,024 10140 0.8 5,000 8112 Max Anticipated Surface Pressure MASP=Lessor of(Frac Pressure @(0.052 X(MW+0.5ppg)X ND)-GasGRD X TVD))or (Max Pore Pressure-(GasGRD X ND)) Hole Sizes Casing Size Max EMW Frac Grad at MW Safety Gas Frac Max PP at MD(ft) ND(ft) Pressure at MASP(psi) (in) (in) (ppg) Shoe Factor Gradient Shoe Next ND 121/4" 9 5/8" 2,000 1,781 8.9 15.2 0.50 0.10 1276 2,209 1,276 81/2" 7" 7,500 6,089 9.8 15.8 0.50 0.10 4552 4,106 4,106 6 1/8" 5" 11,967 10,024 10.2 15.8 0.50 0.10 7494 4,314 4,314 • Max Allowable Surface Casing Pressure MASCP=(0.80 X CASING BURST)-(MW-Pore Pressure)X.052 X TVD Hole Sizes Casing Size Safety Max EMW MD(ft) ND(ft) Burst(psi) MW (Pore MASCP(psi) (in) (in) Factor Pressure) 12 1/4" 9 5/8" 2,000 1,781 6870 0.8 9.2 8.9 5468 8 1/2" 7" 7,500 6,089 7240 0.8 9.8 9.8 5792 6 1/8" 5" 11,967 10,024 10140 0.8 10.5 10.2 7956 Safety Factors Hole Sizes Casing Size Collapse Tension Liner Length SAFETY FACTORS (in) (in) MD(ft) ND(ft) Burst(psi) (psi) (kips) Wt(lh/ft) (ft) Burst Collapse Tension 12 1/4" 9 5/8" 2000 1781 6870 5750 1161 40 - 5.4 8.9 14.5 8 1/2" 7" 7500 6089 7240 5410 641 26 - 1.8 2.2 3.3 6 1/8" 5" 11967 10024 10140 10500 457 18 4767 2.4 2.4 5.3 SF Burst=Burst Value/MASP SF Collapse=Collapse Value/((0.052 X Max EMW Pore Pressure X ND)-(gas gradient X TVD)) SF Tension=Tension Value/(Length X lb/ft) 47 • • Drilling Fluid Program Mi SWACO Cook Inlet Energy,LLC Olson Creek#2 Fluids Program Proposal Summary Olson Creek#2 is a deviated grassroots exploration well that will be drilled utilizing Patterson Rig#191.The objective of the Olson Creek#2 is to test the potential of the lower Beluga and the Tyonek gas intervals. It is proposed that a M-I GEL Spud Mud system be utilized for the 12.25"surface hole section to 2,000'MD.In order to minimize the need of having large quantities of product on hand and also reduce the amount of cuttings that need to be hauled away,it is suggested that a highly inhibitive KLA-SHIELD system be used to drill the 8.5" intermediate interval to 8,500'MD.The KLA-SHIELD system will be comprised of 3%KCL and sized Calcium Carbonate.The 6.125"production interval will also utilize the KLA-SHIELD system and be drilled down to 11,967'MD. Contingency products will be on hand to cover events such as mud weight increases and to combat any lost circulation problems that may occur. Footage Depth Mud Weight Casing Size Hole Size Coin. Intervals Depth MD TVD of Hole Mud System ,. (1)P9)Drilled 13.375" NIA I I 200' 200' NIA NIA NIA 9.625"OD 12.25" 8.681"ID 0.1458 2000' 1,980' Gel Spud Mud 8.8-9.2 bblalft 8.5" Imel 6.184' D 0.0702 8,500' 6,961' 6,500' Kla-Shield 9.0.9.5 bblstft 6.125" 5.0"OD .0364 11,967' 10,024' 3,468' KIa-Shield 9.5-10.5 4.276"ID bblsHt 48 • 12.25"INTERVAL SUMMARY SURFACE INTERVAL Drilling Fluid M-I GEL Spud Mud System Key Products M-I GEL,GELEX Bentonite Extender,POLYPAC SUPREME UL&Soda Ash Solids Control Shakers,Centrifuge Potential Problems Hole Stability Shallow Gas Washout Swelling Clays INTERVAL MUD PROPERTIES Depth MD(ft) Mud Wt. Funnel Viscosity Plastic Viscosity Yield Pointl1b/100ft API Fluid Loss LGS(%) (ppg) rl (m1/30min) 0'-2,000' 8.8-9.2 85-125 20-40 25-45 <9 <13% NOTE:This program is provided as a guide only. Well conditions will always dictate fluid properties and product additions required for well-bore integrity. Surface Interval Overview Lithology through this zone is a composite of sand and small pea gravel in the upper intervals with a grading downward to predominately sand and some siltstone in the lower zones of this interval. Based upon work done on previous wells in this area,an M-I GEL Spud Mud is recommended for the surface interval. Table 4.1:Initial Fluid Makeup for M4 GEL Spud Mud(use fresh water) PRODUCT CONCENTRATION M-I GEL 25-27 Ib/bbl Soda Ash 0.25-0.5 Ib/bbl or as needed GELEX As needed Ido not add until drilling out conductor) Table 4.2:M-1 GEL Spud Mud Additions PRODUCT CONCENTRATION M-I GEL 25-27 lb/bbl Soda Ash 0.25-0.5 Ib/bbl oras needed Caustic Soda As needed for a pH of 9.0-9.5 GELEX As needed for viscosity POLYPAC SUPREME UL 0.25 lbs/bbl or as needed to control fluid loss 49 S 6.125"Interval Summary PRODUCTION INTERVAL Drilling Fluid System KLA-SHIELD Key Products POLYPAC SUPREME UL,DUO-VIS,KCL,KLA-STOP,Busan 1060,DEFOAM-X,ASPHASOL SUPREME,LOTORQ,DRILLZONE,SAFE CARB-20,SAFE CARB-40,M-I WATE,SACK BLACK,CONQOR 404WH&RESINEX Solids Control Shakers&Centrifuge Potential Problems Hole cleaning Loss circulation/Differential sticking Hole stability Running coals INTERVAL MUD PROPERTIES Depth MD(it) Mud Wt. PV Yield Point HTHP Fluid Loss Cl- LGS (ppg) (Ib1100ft2) (lb1100it2) (m1130min) (mgfl) (%) 8500-11,967 9.5.10.5 10-20 15-25 <8 14,000-18,000 <6% NOTE This program is provided as a guide only.Well conditions will always dictate fluid properties and product additions required for well-bore integrity. Production Interval Overview The production interval will be drilled to a depth of 11,967'MD using a 6.125"bit with the highly inhibitive KLA- SHIELD system at 10.5ppg containing 3%KCL.Wellbore stability is crucial to the interval as several coal seams will be drilled.A well maintained mud system supplemented with good solids control equipment for maximum solids removal will minimize fluid invasion.Proper drilling practices and properly engineered fluid will minimize wellbore instability. Any new fluid that is required should be built to the below specs. KLA-SHIELD Drilling Fluid Formulation: Fresh Water 0.88 bbls DUO-VIS 1.0 ppb(as needed for Rheology) POLYPAC SUPREME UL 1.5—3.0 ppb 3%KCI 10.7 ppb(in base brine) M-I WATE As needed for density KLA-STOP 8.0-12 ppb/2.0—3.0%vN DRILZONE 0%-2.0%As needed Busan 1060 0.49 ppb 50 ! • Logging Plan Wireline logging will be LWD Triple combo with the possibility of running the sonic tool. Mud Logging Plan Mud loggers will catch 30' ditch samples and maintain a wet and dry cut. Samples to be sent to state as required by regulations. Mud logging to commence in 8 '/z" hole immediately below the 9 5/8" casing shoe at 2000'. Solids Control and Equipment Item Equipment Specifications Shakers Brandt King Cobra Triple Shaker Desander 3 cone desander Desilter 24 cone desilter Centrifuge TBA Drilling Waste Storage Drilling wastes will be either granular solids (cuttings), or liquids (drilling mud or water). Cuttings and fluids will be stored in a permitted disposal pool and transferred to super sacks for disposal at the West MacArthur grind and inject facility. 51 I • Cementing Program Surface: FLUID SYSTEMS MUDPUSH II System MUDPUSH II Density 11.00 lb/gal Totes Volume 35.0 bbl Additives Code Description Concentration D031 Weighting Agent 3447.71b/mgal Class A Extended Lead Slurry(3.sJ sacks,94 lb per sack of Blend) System Conventional Density 12.00 lb/gal Yield 2A4 ft3/sk Mix Water 14.329 gal/sk Mix fluid 14.479 gal/sit Total Volume 157.0 bbl Code Description Concentration Class A Cement 94 ib/sk WBWOB Additives D110 Retarder 0.150 gal/sit VBWOC 0046 Anti-Foam 0.2%BWOB D079 Extender 2.0%BWOB 0020 Extender 2.6%BWOB Class A Tail Slurry 1284 sacks,9418 per sack of Blend) System Conventional Density 15.40 lb/gal Yield 1.22 ft3/sk Mix Water 5.507 gal/sit Mix Fluid 5.507 gal/sit Total Volume 61.6 bbl Code Description Concentration Class A Cement 94 lb/ak WBWOB Additives 0046 Anti-Foam 0.2%BWOB D065 Dispersant 0.4%BWOB S002 CaCl2 0.2%BWOB H2O System Water Density 8.34 lb/gal Additives t 5.0 bbl � Total Volume _._ Code Description Concentration 52 I 4110 Intermediate JOB AT A GLANCE Depth(TVD) 6,961 ft Depth(MD) 8,500 ft Hole Size 8.5 in Casing Size/Weight lin, 29 lbs/ft Pump Via T'O.D. (6.184".I.D) 29 Total Mix Water Required 833 gals Weighted Spacer Seal Bond 40 bbls Density 10.5 ppg Cement Slurry Class G 169 sacks Density 15.8 ppg Yield 1.15 cf/sack Displacement Drilling Mud 313 bbls 53 • WELL DATA ANNULAR GEOMETRY ANNULAR I.D. DEPTH(ft) (in) MEASURED I TRUE VERTICAL 8.681 CASING 2,000 1,781 8.500 HOLE 8,500 6,961 SUSPENDED PIPES DIAMETER (in) WEIGHT DEPTH(ft) O.D. I.D. (lbs/ft) MEASURED TRUE VERTICAL 7.000 6.184 29 I 8,500 6,961 Float/Landing Collar set @ 8,420 ft Mud Density 9.50 ppg Est.Static Temp. 126° F Est.Circ.Temp. 107°F VOLUME CALCULATIONS 1,000 ft x 0.1268 cf/ft with 40% excess = 177.5 cf 80 ft x 0.2086 cf/ft with 0% excess = 16.7 cf(inside pipe) TOTAL SLURRY VOLUME = 194.2 cf 35 bbls FLUID SPECIFICATIONS Weighted Spacer 40.0 bbls Seal Bond+110 lbs/bbl Barite-Sacked 10.5 ppg VOLUME VOLUME FLUID CU-FT FACTOR AMOUNT AND TYPE OF CEMENT Cement Slurry 194 / 1.15 = 169 sacks Class G Cement+0.005 lbs/sack Static Free+0.2%bwoc R-3+0.3%bwoc CD-32+0.5% bwoc FL-62+ 1 gals/100 sack FP-6L+43.7% Fresh Water Displacement 312.8 bbls Drilling Mud CEMENT PROPERTIES SLURRY NO.1 Slurry Weight (ppg) 15.80 Slurry Yield (cf/sack) 1.15 Amount of Mix Water (gps) 4.93 Amount of Mix Fluid (gps) 4.94 Production 54 • • MUDPUSH II System MUDPUSH II -- ----- ------- Density12.00 lb/gal Total Volume — — 35.0 bbl Additives Code Description ________ D031 Weighting Agent 4748.2 Ib/ngal EASYBLOK Production Slurry(3`Ri F31,m:11 System Conventional Density 15.30 lb/gal Yield 135 113/sk Mix Water 5.937 gal/sk Mix fluid 5.937 gal/sk Total Volume _ 85.7 bbl Expected Thickening Time 100 8c at 05:24 hr:mn Expected ISO/API Fluid Loss 13 mL in 30.0 min Coda Description Concentration G Cement 94 lb/sk WBWOB D046 Anti Foam 02%BWOB Additives D202 Dispersant 1.0%BWOB 0400 Gas Control Agent 0.8%BWOB 0154 Extender 8.0%BWOB D174 Expanding Agent 1.0%BWOB D198 Retarder 0.2%BWOB H2O System Water Density 8.34 lb/gal Total Volume 5.0 bbl Additives Code Description Cenceotratlon 55 HALLIBURTO ®`a.a. 12-114" (311 mm) FX56M PRODUCT SPECIFICATIONS Cutter Type X3-Extreme Drilling IADC C ode M222 B odyType MATRIX or Total Cutter Count 46],fir Cutter Distribution MEM Face 0 0 30 " Gouge 5 5 1 t al ,Up Drill 5 0 0 4110 Ill 4. Number of Large Nozzles 5 r N Number of Medium Nozzles 0 "ri,! Number of Small Nozzles 0 y,: ' er Number of Micro Nozzles 0 , Number of P orts(Size) 0 N�1 ' Sir. Number of Replaceable Ports(Size) 0Wille‘ P.' 'f Junk Slot Area(sgin) 28.02 �'' NormalizedFace V olume 5121% API Connection 6-5/8 REG.PIN Recommended Make-UpTorque* 37,119-43,525Ft*lbs. �m- q . Nominal Dimensions** f°.Y" Make-Up Face to Nose 14.92 in-379mm Gauge Length 4 in-102 mm Sleeve Length 0 in-0 mm Shank Diameter 8.75 in-222 mm Break OutPlate(Mat#/Legacyk) 181955144050 Approximate Shipping Weight 420Lbs.-191Kg. SPECIAL FEATURES f. Impact Arrestor;1/32"Relieved Gage,Up-Drill Cutters on G age Pads,H ex agora TS P Gage Material#663911 *Bit specific re caeueended make-up torque is a Surction of the bit I.D.and actualbit sub O.D.utilized as specified in API RP7G S ection A.8.2. **Design dimensions are nominal and may vary slightly on manufactured product.HallilurtonDrill Bib and S ervices motels an continwusly reviewed and refired. Product specifications may change without notice. ©2013 H alliburton.All rigltsreserve d.S ales of Halliburton products and services will be in accord solely with the terms and conditions contained inthe contract betweenHalliburtonand the customer that is applicable to the sale. www.hallibuctoiu otn 56 • • HALLIIIILIPITON ri..r -112" (216mm) FX74D PRODUCT SPECIFICATIONS Cutter Type X3-Extreme Drilling p + IADC C ode M434 BodyType MATRIX Total Cutter C cunt 93 e i` Cutter Distribution jai „;, r Face 67 Gauge 19 ' 4;o4ir*4 R Up Drill 7 i' Number of Large Nozzles 0 • $ Number of Medium Nozzles 0 Number of Small Nozzles 6 Number of Micro Nozzles 0 Number of Ports(Size) 0 Number afReplaceable Ports(Size) 0 Junk Slot Area(sgin) 12.68 Norm aliz ed F ace V plum a 39.67% „ API Connection 4-1/2 REG.PIN Recommended Make-Up Torque* 12,461—17,766 Ft*1bs. ;„i> a•+ Nominal Dimensions** •�' a �- Make-Up Face to Nose 12.98 in-330 nun Gauge Length 4 in-102 rare Sleeve Length 0 in-0 mm ` Shank Diameter 6 in-152 mm41t- Break Out Plate(Mat#/Legacy#) 181954144040 Approximate Shipping Weight 170Lbs.-77Kg SPECIAL FEATURES Up-Drill Cutters on Gage Pads,Hex egon TSP Gage,OptimizedDual Row-"D”Feature Material#661050 *Bit specific leconunended make-up torque is a Sanction&the bit I.D.aid actualbit sub O.D.utilized as specified in API RP7G S ectionA.8.2. **Design dimensions are nominal and may vary slightly ottmamrfacbored product.HalliiurtonDrill Bits and S ervices models am continuously reviewed and refined. Product specifications may change without notice. ©2012 Halliburton All rights reserved.S ales of Helliburtonproducts and services will be in accord solely with the terms and conditions contained inthe c wits actb etw a en H allibuiton and the customer that is applicable to the sale. www.hallibta-ton.com 57 • HALLIBURTON 6-1/8" (156mm) MM64D PRODUCT SPECIFICATIONS Cutter Type SelecCutter IADC C ode M434 BodyType MATRIX Total Cutter Count 55 Cutter Distribution lOmm 1322m Face 12 25 h Gauge 0 12 1111r, Isor Up Drill 0 6 Number of Large Nozzles 0 Number of Medium Nozzles 0 Number of Small Nozzles 0 ,. Number of Micro Nozzles 6 Number of Ports(Size) 0 Number of Replaceable Ports(Size) 0 r Junk Slot Area(sgin) 537 NormalizedFace Volume 2599% ♦ria API Connection 3-1/2 REG.PIN eeee te Recommended Make-Up Torque* 5,173-7,665Ft*lbs. :lee t N ceninal Dimensions** Make-Up Face to Nose 9.35 in-237 mm Gauge Length 2 in-51 mm Sleeve Length 0 in-0 mm Shank Diameter 45 in-114 mm Break OutPlate(Mat#/Legacylt) 181953144030 Approximate Shipping Weight 90Lbs.-41Kg SPECIAL FEATURES Up-Drill Cutters onGage Pads,1/32"RelievedG age,Optimized Dual Row-"D"Feature Material#780706 *Bit specific re commended make-up torque is a function of the bit I.D.and actual bit sub O.D.utilized as specified in API RP%S ectionA.8.2. **Design dimensions are nominal and may vary slightly onmarmfachtred product.HallrburtonDrill Bib and S ervices models ate continuously reviewed and refined. Product specifications may change without notice. ©2013 Halliburton All rights reserved.Sales of Halliburton products and services will be in accord solely withthe terms and conditions contained inthe contract betweenHelliburtonand the customer that is applicable to the sale. www.h lllbztrt ln,carh 58 S Regulatory Waiver and Special Procedures Requests AOGCC Regulation 20 AAC 25.235 Gas Disposition CIE requests permission to vent or flare gas from the WMRU-08 well test for a period of 14 days according to 20 AAC 25.235 d(6). Maximum anticipated daily flaring is expected to be 1MMSCF/D with a total expected not to exceed 10 MMSCF over the entire test. If the well is successful, it will be tied into the West McArthur production facility. AOGCC Regulation 20 AAC 25.265 Automatic shut-in equipment a well that is capable of unassisted flow of hydrocarbons to surface and that has an onshore surface location that is 660 feet or less of (A) a permanent dwelling intended for human occupancy, including a billeting camp or private residence; (B) an occupied commercial building, excluding a structure located within an existing oil or gas field; (C) a road accessible to the public; (D) an operating railway; (E) a government maintained airport runway; (F) a coast line measured at mean high water; (G) a public recreational facility; or (H) navigable waters as defined by the United States Army Corps of Engineers in 33 C.F.R. Part 329.4 with boundaries defined in 33 C.F.R. 329.11; The Olson#2 exploration well is located on a logging type road which is not considered as public access. Cook Inlet Energy does not intend to install a SSSV should the well be completed and requests confirmation from the AOGCC that it would also not consider the well road as a public access way. 59 t tiY CU STATE OF ALASKA J U L 1 S 2014 WKA OILAND GAS CONSERVATION COMMIS�J PERMIT TO DRILL 20 AAC 25.005 ` C 1 a.Type of Work: 1 b.Proposed Well Class: Development-Oil _ Service- Winj Single Zone 1 c.Specify if well oposed for: Drill ® Redrill 1=1Stratigraphic Test Development-Gas — Service-Supply Multiple Zone Coalbed Gas /02Gas Hydrates Re-entry e Exploratory Service- WAG Service-Disp Shale Gas 2.Operator Name: 5. Bond: Blanket Single Well e 11.Well Na' 'and Number: COOK INLET ENERGY,LLC Bond No. 1212870 }• -ON CREEK WELL#2 3.Address: 6.Proposed Depth: 12.Fie.r-ool(s): 601 W 5TH AVE ANCHORAGE,ALASKA 99501 MD: 11,967 TVD: 10,024 / 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): / EXPLORATORY Surface: 2593'FWL,2931'FNL,Sec 6,T13N,R10W SM MHT 9300062 / Top of Productive Horizon: 8.Land Use Permit: i/ 3.Approximate Spud Date: MHT 9300062 / 8/1/14 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 5483 2,640'FNL,2,640'FEL 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 18 15.Distance to Nearest Well Open Surface: x- 264980 y- 299832 Zone- 4 GL Elevation above MSL: /291.5 to Same Pool: N/A 16.Deviated wells: Kickoff depth: 600 feet' 17.Maximum Anticipated Pressures in 0(see 20 MC 25.035) Maximum Hole Angle: 51 degrees Downhole: 3559 psi Surface: 4314 psi 18.Casing Program: Specifications Top - Setting Depth -;Bottoq Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD '\ TVD (including stage data) Driven 13 3/8" 68# L80 BTC 200' 0 0 2 1,@_ 2��-Q```0,_ - 12 1/4" 9 5/8" 40# L80 BTC 2,000' 0 0' 2,000 6 1 Jy�r, 142 sxs 8.5" 7" 29# L80 BTC 8,500' 0 0 0 ' 6, 170 sxs 6 1/8" 5" 18# L80 BTC 4,767' 7,200' 5,8 1' 1 7' 10,024' 376 sxs \ A 19. PRESENT WELL CONDITION SUMMARY(To be completed for Re.rill Tv a-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effe. aepth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Size L. ement Volume MD TVD Conductor/Structural Surface r,— Intermediate 9 Production Perforation Depth MD(ft): / Perforation Depth TVD(ft): 20. Attachments: Property Plat ® BOP Sketch Drilling Program izi Time v.Depth Plot Shallow Hazard Analysis @ Diverter Sketch ri Seabed Report Drilling Fluid Program p'4 20 MC 25.050 requirements r4 21. Verbal Approval: Commission Representative: Date 18-Jul-14 22. I hereby certify that the foregoing is true and correct. Contact Courtney Rust 433-3809 Printed Name Conrad Perry Title Drilling Manager Signatures.— 1�'Al - fort wni"N C' mi Phone 907-727-7404 Date 7/18/14 Commission Use Only Permit to Drill IAPI Number: Permit Approval See cover letter for other Number: 50- Date: requirements. Conditions of approval: If box' checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: Other: Samples req'd: Yes e Noe Mud log req'd: Yes B No- H2S measures: Yes No Directional svy req'd: Yes No APPROVED BY THE COMMISSION DATE: ,COMMISSIONER i ORIGINAL Form 10-401(Revised 7/2009) This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Submit in Duplicate • ID _ Cook Inlet Energy_ JUL 1®G 8 C2014 C July 18, 2014 Ms. Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill Cook Inlet Energy, LLC: Olson Creek#2 Dear Ms. Foerster, Cook Inlet Energy (CIE) hereby submits a completed Form 10-401 and Permit to Drill application for the Olson Creek#2 well located on CIE lease #MHT 9300062, Also, attached are proposed wellbore schematics, MASP calculations, Rig Drawing, and a BOP configuration diagram. Patterson Rig - 191 will be used to complete this work, commencing approximately August 1, 2013. Maximum Anticipated Surface Pressure for this well is 4314 PSI. Please note waiver and permission to flare requests are located at the end of this submittal. If you have any questions,please contact me at(907) 727-7404. Sincerely, j C Fust ?Ectal Conrad Perry Drilling Manager Cook Inlet Energy 601 W.5'h Avenue,Suite 310,Anchorage,AK 99501 (907)334-6745*(907)334-6735 fax • • RIG#191 SCHEMATIC AND PAD ORIENTATION 1 LOCATION PLAT 2 DRILLING PROCEDURE-OLSON CREEK 2 3 FORMATION INTEGRITY TEST PROCEDURE 7 PROPOSED WELLBORE DIAGRAM 8 OLSON CREEK 2 ANALYSIS 35 GEOMECHANICAL PLOT- 45 LOGGING PLAN 51 MUD LOGGING PLAN 51 SOLIDS CONTROL AND EQUIPMENT 51 DRILLING WASTE STORAGE 51 CEMENTING PROGRAM 52 SURFACE: 52 INTERMEDIATE 53 PRODUCTION 54 BIT PROGRAM 56 REGULATORY WAIVER AND SPECIAL PROCEDURES REQUESTS 59 • • Rig #191 Schematic and Pad Orientation ii 0 c L�- —.. —6.-9 0 fTl DNor, r y y ,r r_..,-1 VS � "o _ 1 t z m 'i I i r 111 rn i ..i� W App 1 S v — 1 - ' w�� i 11-71-1:i1 W Kw 1 1 7 z -- 7'-9.. ---Till 0 1 ,..'} co I i D d111 M ZC t S 1 •�ii o { &' I „ ''i 1 j II rig { 3piOC, 1, rn'1�T_ ■ ZO.3• 1 kill 1 m 7% 54Z ( 0 A kCC —c •'1 N . 0 .., t ) -7. 1s-441:, �m2 ' 11 111§< o- 77 6 4 7 E _ 80 — — ' 7" I 57'-6" 0 0! 1 ' oD 8 • -- —146'-11" - J Z O P 0 n _..-1-... 1 • • Location Plat 2 • • Cook Inlet Energy_ Drilling Procedure - Olson Creek 2 Pre-Spud 1. Stake Well Location 2. Drive 20" conductor to refusal at+/- 100'. 3. Install Mouse hole 4. Install 8' Well Cellar 5. Install 20" starting head 6. Clear and prep location Drilling General Note: Full opening Safety Valve will be on rig floor at all times with appropriate crossovers for all pipe being run below rotary table. 1. Move in and Rig Up Patterson 191. 2. Nipple up 21 1/4" diverter and 12 1/4" diverter lines, if required. Function test system prior to AOGCC witness. a. 48 hours' notice for remote operations 3. Pick up and stand back 5" drill pipe. 4. Function test diverter and witness by AOGCC. Give 48 hour notice. 5. Pick up 12 1/4" BHA: a. 12 1/4" MX-1 bit b. 8" Mud Motor with 1.22 bend c. 8" Stabilizer d. MWD w/GR e. 3 Flex Collars f. Weatherford 7-3/4"jars g. 21 Joints HWDP. 6. Clean out conductor and spud well. Note time and date in report. 7. Drill 12 1/4" vertical hole to 500' kick off point, per directional plan. 8. Directionally drill 12 1/4" hole to 2013'MD/1790'TVD. 9. Circulate Hole Clean. Check for Flow. POH. Stand back directional tools. 3 • • a. Note: If any sign of swabbing, run back to bottom immediately. b. Pump/Rotate out of hole if necessary. 10. Rig up to run 9 5/8" casing. 11. Run 9 5/8", 40#, L80 Buttress casing to +/- 2,000' with Float Shoe and Stab-in float Collar on joint up. Land casing elevators on wood blocks close to RT. a. Centralize casing i. One per joint on first 4 joints ii. One per 4 joints to conductor. 12. Make up false rotary and surface flow nipple. 13. Pick up cementing stinger and centralizer. 14. RIH on 5" drill pipe. 15. Stab into float collar. Establish circulation slowly. 16. Rig up cementers and test lines. 17. Pump 12.5 ppg lead cement until returns to surface. Tail with 500' of 13.0 ppg. Plan to use 100% excess, per cement program. Dump excess cement into cellar. Have cement retarder on hand. 18. Un-sting from collar and check for back flow. Drop wiper ball and circulate drill pipe clean. 19. POH with drill pipe. Rig down false rotary. 20. WOC for 12 hours minimum. a. Check for flow on both inside and annulus. b. Lift riser& make rough cut on 9 5/8" casing. c. Lay down casing stub. d. Nipple down diverter. 21. Nipple Down Diverter. Dress conductor and 9 5/8" casing. Check for cement to surface. Perform top job if cement is not at surface. 22. Install, weld, and test Vetco 5M 13 5/8" multi-bowl wellhead. Orient to match existing wellheads on pad. 23. Nipple up and test 13 5/8" BOPE with 3 '/2" x 5" VBR pipe rams, Blinds in middle. a. Test Rams to 3500 psi b. Test Annular Bag to 2500 psi. 24. Clean pits and make up new mud system. 25. Pick up and stand back sufficient 5" drill pipe if not done already. 26. Pick up 8 '/2" BHA: a. 8 1/2" PDC Bit b. 7 5/8" Mud Motor c. MN Stabilizer d. 6 3/4" MWD-GR e. PWD Sub f. NM Stabilizer 4 • . g. 3x63/4"NMDC h. 6 Joints HWDP i. Jars j. 14 Joint HWDP 27. RIH to 1000'. Perform shallow MWD test. 28. Continue RIH. Test Casing to 3000 psi. Drill out float collar, shoe track and float shoe. Drill 20' of new formation. Circulate and condition mud. a. Perform FIT to minimum 12.0 ppg EMW(Take to leak off pressure) 29. Directionally drill 8 %2"hole to 8,500' MD/6,961' TVD,per directional plan. 30. Circulate hole clean with minimum of three bottoms up. Preferred procedure is first circulation on bottom, pull a stand for the next, and same for the third and fourth if necessary. Pull out of hole. Avoid back reaming if possible. Pump out of hole, if necessary. 31. Lay down all smart iron and expedite back to Halliburton. 32. Make wiper trip if needed. 33. Rig up to run 7" casing. Change upper rams to 7" and test to 3000 psi. 34. Run 7", 26#, L80 BTC to bottom. a. Centralizer program to be as follows: i. 1 Solid body spiral centralizer every joint through planned TOC. ii. 1 Solid body spiral centralizer every 4th joint thereafter. b. Break circulation at 5000' and 9 5/8" shoe, and every 2000' in open hole. c. Note swab and surge pressures of tripping are excessive with 7" casing in 8 1/2" hole at this depth. 35. Circulate and condition hole. Reciprocate casing while circulating. 36. Rig up and test cementers. Cement 7" casing according to program. Continue reciprocating casing while pumping cement. Land Casing and Bump plugs with 3000 psi. Release pressure and check floats. a. Ensure cement is a minimum of 1000' above top of highest known hydrocarbons. 37. Set and Test 7"packoff to 5000 PSI 38. Lay Down 5" Drill Pipe. 39. Change and test Upper Rams to 3 1/2" x5". Test BOPE on 4" and 5"to 5000 psi/Hydril to 2500 psi. 40. Pick up and stand back 4" drill pipe. 41. Pick up 6 1/8" BHA: a. 6 1/8" PDC bit b. 4 3/4" Mud Motor c. Stabilizer d. 4 3/4" MWD/Triple Combo e. Ported Float Sub f. Stabilizer 5 • • g. 3 x 4 3/4"NM Flex Collars 42. RIH on 4" drill pipe to float collar. Test casing to 5000 psi. 43. Drill out float collar, shoe track and float shoe. 44. Drill 20' of new formation. Circulate and condition mud. Perform FIT to minimum 10.5 ppg EMW (10.5 ppg is minimum, take to leak off pressure). 45. Directionally drill 6 1/8" hole to TD at 11,968' MD / 10,024' TVD, per directional plan. a. Note swab and surge pressures of tripping are excessive at this depth. Consider pumping out of the hole on any trip. b. This section will be almost entirely in the productive horizon. c. Note transition zones and reduce ROP when drilling through coals 46. Circulate hole clean with minimum of three bottoms up. Preferred procedure is first circulation on bottom, pull a stand for the next, and same for the third and fourth if necessary. 47. Pump out to 7" shoe or make wiper trip then POH. 48. Pick up Weatherford Triple combo memory shuttle log. RIH on drill pipe to TD. Circulate bottoms up. POH logging as directed to 9 5/8" shoe. —Confirm logging run and depth interval with CIE office. 49. Rig up to run 5" liner. Change upper rams to 5" and test to 5000 psi. 50. Run 5"; 18#; L-80; BTC Liner to bottom. a. Centralizer program to be as follows: i. 1 Solid body spiral centralizer every joint through planned TOC. ii. 1 Solid body spiral centralizer every 4th joint thereafter. b. Break circulation at 5000', 7,500', and every 2000' in open hole. c. Note swab and surge pressures of tripping are excessive with 5" liner in 6 1/8" hole at this depth. d. Top of liner to be 300' inside 7" casing shoe. 51. Circulate and condition hole. Reciprocate liner while circulating. 52. Rig up and test cementers. Cement 5" liner according to program. Continue reciprocating liner while pumping cement. Bump plugs with 3000 psi. Continue pressuring up, setting Liner/Hanger-Packer, per Service Company's Procedure. Release pressure and check floats. Un-sting from liner. a. Ensure cement is a minimum of 1000' above top of highest known hydrocarbons. 53. Circulate out excess cement. 54. POH laying down all 4" drill pipe. 55. Change and test ram to 5000 psi on 3 '/2" and 2 7/8". Pick up 4" mill and 5" scraper and RIH picking up 2 7/8 Tubing. 56. Clean out 5" liner to landing collar. Circulate hole clean. Test casing and liner lap to 5000 psi if past 24 hour CIP. Change over to completion fluid using appropriate spacers. 57. POH & stand back tubing. 58. Run CBL. Prepare squeeze program if necessary. 6 • • 59. Pick up TCP completion/packer and jewelry. 60. RIH on 2 7/8" tubing. 61. Run GR gun correlation log. Set TCP on depth and confirm. 62. Set Packer and test tubing to 3000 psi for 30 minutes. Test annulus to 3000 psi for 30 minutes. 63. Nipple down BOPs. Nipple up and test tree. 64. Release rig. 65. Open sliding sleeve and displace tubing to crude oil. Set jet pump in sleeve. 66. Cycle well pressure and fire guns. 67. Flow well. Formation Integrity Test Procedure Surface and Intermediate casing shoes will be tested to Leak-off. Prior to drilling out of casing strings, test BOPs, and casing to the specified pressure listed in the BOP Program section. Plot test and record volume required on the drilling report. Leak-off tests (LOT) are to be conducted as described below: • Drill 20' to 25' of new formation below the casing shoe and condition the mud to the same properties in and out. • Pull drill bit into the casing shoe and close pipe ram preventer. Line up to the choke manifold with a closed choke. • Begin slowly pumping fluid down the drill string at 1/2 bpm while recording casing and drill pipe pressures at 1/2 bbl intervals. • A running plot of pressure versus volume should be kept by the Drill Site Manager while the test is in progress. • Stop pumping when the pressure curve departs form a straight line sufficiently to indicate leakage into the formation. Record as ppg equivalent mud density in the IADC and morning reports. • Monitor and plot pressure drop and time after shut-in for 10 minutes or until the shut-in pressure stabilizes. 7 • • Proposed Wellbore Diagram Olson Creek#2 Proposed Completion 1/1/14 1 161 3/8" L80 200'ND 68# BTC 200'MD • • 12 1/4"Hole LA 46, 9 5/8" L-80 1,781'ND 40# BTC 2000'MD TOL t 7200'MD , 8.5"Hole 7" L80 6,961'TVD 29# BTC 8500'MD Sliding Sleeve @ 9,500'MD Hydraulic Set Packer la 9,700' XN Nipple(dl 9,750' 2 7/8"L80 EUE Tubing J 6 1/8"Hole 5 L80 10.024'ND 18# BTC 11,967'MD 8 • 0 Time vs. Depth Plot WF-03 Time vs Depth Chart Rig Drys on Location 0 5 10 15 20 25 30 35 40 45 50 55 60 65 70 0 I 1000 Drell wfsx Me I 2000 3000 . sago ND Lfveita,NU BOP,LOT 1I 4 4000 : I w 5000 I 6000 Dol I,,, hple 1 7000 E I 8000 I I . ! I 9000 10000 Drill ft.5 }Tole Section 'i � I 11000 /1 IP 12000 13000 1 14000 - , ' 15000 1i 16000 17000 l 18000 19000 I I ! f 9 • • Directional Plan K R•■ Cook Inlet Energy Cook Inlet Energy BA Location: Cook Inlet,Alaska(Kenai Pennsula) Slot: 01son2 Slot HUGHES Field Olson Creek Unt Well. Olson2 Facility Olson Creek Wellbore Olson2 WelPlan Plot reference wellpath is Olson 2 Ver1f5 True vertical depths are referenced to Rig on Olson 2 Slot(RT) Grid System.NAD27/TM Alaska SP,Zone 4(5004),US feet Measured depths are referenced to Rig on Olson 2 Slot(RT) North Reference:Grid north Rig on Olson 2 Slot(RT)to Mean Sea Level:324 4 feet _ Scale True distance Mean Sea Level to Mud line(At Slot Olson 2 Slot) 0 feet Depths are in feet Coordinates are in feet referenced to Slot Created by.ulricard on 151Ju1/2014 Well Profile Data Design Comment MD(It) Inc(°) Az(°) TVD(It) Local N(R) Local E(0) DLS(°/10011) VS(II) Tie On 0.00 0.000 283.720 0.00 0.00 0.00 0.00 0.00 End of Tangent 500.00 0.000 283.720 _ 500.00 0.00 0.00 0.00 0.00 End of Build 1888.30 51.050 283.720 1711.77 137.24 -562.12 3.68 578.02 End of Tangent 2013.00 51.050 283.720 1790.16 160.24 -656.33 0.00 674.89 End of 3D Arc 2410.70 37.620 280.834 2074.00 220.01 -927.05 3.41 952.05 End of 3D Arc 2420.90 37.930 280.830 _ 2082.06 221.19 -933.19 3.04 958.30 End of Tangent 7446.50 37.930 280.830 6046.07 801.64 -3967.39 0.00 4047.50 End sf30 Arc 7777.90 27.990 280.400 _ 6323.78 834.90 -4144.37 3.00 4227.57 End of Tangent 11967.90 27.990 280.400 10023.67 1189.88 -6078.50 0.00 6193.87 Eastin g(ft) -7000 .1.1.1.2[130-6000 -5000 -4000 -3000 -2000 -1000 0 10 -.1250- I-- t t r r a t 4 �t000 ;� 'Jlson 2;.V;41;-.4,--0 G,.p9 1r I 0. 7 '1 Tie On TD_P3 4. . 1000 z d 13.375in Conductor o End o1 Tangent yonek_PJ T24g_P3 D 4_ 'o 1250- 3.66910011 le' � Olson 2 slot_ 0 .' ara 0625n Cestrg`�v3.41'M 00tt 68r� cao4 7244p3 3.04'f101311 End of 3D Arc 0. 6 SGo ,<1 2500- '�� --1000 3750 c an 5000. 0 to u End ofTangert j 6250- 3.00910011 End or 3DArc m I- 7in Casingp 7500. 8750 10000• TD P3 net ofTangert O P. 11250. 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JW W U tiI me.'mm8�'mm8o�>rmg8w aoaVW8rOS3 'U'3�P.' r3 N IteSq� 5p N N N¢N1 N N N N N N N N N N N N m ANO N N N N N N Nd N N N N N N N N N $888 $$ $ 888 823®V!-�$BS$��J8888BWG8888888$W mmmm mm rW4MINm�mm� 88 k3el $8= Wainmo3�m�8eZ8M0.9siss stiA834C88$ aaR8g $$-N.r>mJm23Q'C38i"�d3 3�381�{d I 12 • • cell Clearance Report If"iiiiill Cook Inlet EnerOlson 2 BAKER Energy Closest Approach Page 1 of 25 HUGHES Operator Cook Inlet Energy Slot Olson 2 Slot IArea !Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek j l REPORT SETUP INFORMATION Projection System NAD27/TM Alaska SP,Zone 4(5004), Software System WellArchitect®4.0.1 US feet North Reference Grid User Ulricard Scalej0.999946 Report Generated 103/Jun/2014 at 15:10 Convergence at slot}1.00°West Database/Source file`WA Anchorage Server/Olson 2 WellHan_CRamd WELLPATH LOCATION Local coordinates Grid coordinates Geographic coordinates North[ft] East[It] Easting[US ft] Northing[US 8] Latitude Longitude Slot Location __gym 0.00 0.00 299832.00 2648980.00 61°14'44.259"N 151°08'11.361'W Facility Reference Pt i 299832.00 2648980.00 61°14'44.259"N 151°08'11.361'W Field Reference Pt I I 299862.99 2648974.54 61°14'44.211"N 151°08'10.726"W WELLPATH DATUM Calculation method Minimum Curvature D gtur�n Olson 2 Slot(RT)to Facility Vertical 324.40ft Horizontal Reference Pt Slot Rig on Olson 2 Slot(RT)to Mean Sea Level 324.40ft Vertical Reference Pt Rig on Olson 2 Slot(RT) Rig on Olson 2 Slot(RT)to Mud Line at Slot 324.408 (Olson 2 Slot) MD Reference Pt Rig on Olson 2 Slot(RT) Field Vertical Reference 'Mean Sea Level S 1 POSITIONAL UNCERTAINTY CALCULATION SETTINGS Ellipse Confidence Limit 3.00 Std Dev Ellipse Start MD 324.408 Surface Position Uncertainty induded Declination 17.04°East of TN Dip Angle 74.08° Mag Field Strength 55651 nT Slot Surface Uncertainty @1 SD Horizontal 2.0008 Vertical 1.00011 __ Facility Surface Uncertainty @1 SD Horizontal 20.00011 Vertical 3.0008 _ Positional Uncertainty values in the WELLPATH DATA table are the projection of the ellipsoid of uncertainty onto the vertical and horizontal planes €1 13 s • oB Clearance Report iraa-u Olson 2 Ver#4 Cook Inlet Energy 1; Closest Approach BAKER Page 2 of 25 HUGHES REFERENCE WELLPATH IDENTIFICATION ___ _________ _____i Operator Cook Inlet Energy Slot -Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek ANTI-COLLISION RULE (Rule Name E-type Closest Approach w/Hole&Csg Limit:0,StdDev:3.00 Rule Based On Ellipsoid Separation w/Surface Uncert Plane of Rule Closest Approach Threshold Value O.00ft Subtract Casing&Hole Size yes Apply Cone of Safety no HOLE&CASING SECTIONS-Ref Wellbore Olson 2 WelLPlan Ref Wellpath:Olson 2 Ver#4 StringIDia<neter Start MD End Ml) Interval Start TVD End TVD Start N/S Start EJW End N/S End E/W [ft] [ft] [ft] [ft] [ft] [ft] [ft] [ft] [_ft] 113375in Conductor 1 0.00 200.00 200.00 0.00 200.00 0.00 0.00 0.00 0.00 19.625in Casing 0.00 2000.00 2000.00 0.00 1781.99 0.001 0.00 157.84 -646.51 r7in Casing 0.00 7500.00 7500.00 0.00 6088.72 0.00r 0.00 807.69 -3999.11 5inLiner 7200.00 11968.00 4768.00 5851.64 NA 773.17 -381857 NA NA SURVEY PROGRAM- Ref wellbore:Olson 2 WdlPlan Ref Wellpath:Olson 2 Ver#4 Start MI) End MI) Positional Uncertainty Model L og Name/Comment Wellbore [III [n] 324.40 11967.90NaviTrak(MagCorr) Olson 2 WellPlan CALCULATION RANGE&CUTOFF From:O.00ft MD To:11967.9011 MD C-C Cutoff(none) OFFSET WELL CLEARANCE SUMMARY(4 Offset Wellpatlrs selected)Ellipse separations calculated in Closest Approach plane I C-C Clearance Distance ACR Ellipse Separation Distance Ref Min C-C Diverging Ref MD of Min Min Ell Sep ACR Offset Offset Offset Offset Offset MD Clear Dist from MD Min Ell Sep Ell Sep Dvrg frun Status Facility Slot Well Well,ore Wellpath [ft] [ft] [ft] [n] 1111 [R] 01so1 Creek Olson 1 Slot Olson 1 Olson 1 Olson 1 1205.00 31.15 205.00 417.90 20.41 417.90 PASS (Olson Creek Olson 1 Slot Olson 1 PBI Olson I PSI Olson 1 PBI 1205.00 31 15 205.00 417.90 20.41j 417.90 PASS frier Otter#1 Otter#1 Otter#1A NaviTrakMWD<4436-7021'> 1160.00 38436.41 160.00 68443 38321.98 684.43 PASS l mer ,Otter#1 Otter#1 Otter#1 Otter#1<0-5686> 1160 00 38436 41 160.001 68443 38322.09 68443 PASS 1 a 14 cea Clearance Report FAN" Cook Inlet EnergyOlson 2 Ver#4 B� Closest Approach Page 3 of 25 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot 'Olson 2 Slat Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek CLEARANCE DATA-Offset Wellbore:Olson 1 Offset Weupath:Olson 1 Facility:Olson Creek Slot:Olson 1 Slot Welt Olson 1 Threshold Yalu i0.00 ft t=interpolatedlextrapolated station Ref MD Ref TYD Ref North Ref East Offset MD Offset TVD Offset North Offset East Horiz C-C ACR Ellipse ACR [R] [rt] [It] [R] pt] [R] [ft] [R] Bearing Clear Dist MASD Sep Status PI [R] [rt] [R] 0.00 0.00 0.00 0.00 1530 32.80 -5.49 30.99 100.05' 45.46 1.01 44.45 PASS 100.001- 100.00 0.00 0.00 8238. 100.08 -5.04 30.98 99.24 31.39 1.01 30.38 PASS 200.001- 200.00 0.00 0.00 18256; 200.02 -2.48 31.05 94.56 31.15 0.88 30.28 PASS 205.001- 205.00 0.00 0.00 187.50 204.96 -2.28 31.07 94.20 31.15 0.72 30.43 PASS 300.001- 300.00 0.00 0.00 '282.43 299.78 2.17 3138 86.05 31.45 0.72 30.73 PASS 400.001- 400.00 0.00 0.00 382.16 399.35 7.83 31.80 76.16 32.76 11.65 21.11 PASS 417.90` _417.90 0.00 0.00 400.00 417.15 8.95 31.90 74.33 33.14 12.72 20.41 PASS 500.00 500.00 0.00 0.00 481.79 498.76 14.50 3236 65.87 35.48 12.75 22.74 PASS 600.001- 599.93 0.76 -3.12 581.29 597.95 22.22 32.93 59.24 42.00 12.93 29.07 PASS 700.001- 699.45 3.04 -12.45 68039 696.67 30.89 33.44 58.75 53.75 13.44 40.31 PASS 800.001- 798.15 6.83 -27.97 778.67 794.46 40.66 33.69 61.25 70.43 14.12 56.31 PASS 900.001- 895.62 12.11 -49.60 875.84 891.00 51.74 33.61 64.53 92.28 14.72 77.56 PASS 1000.001- 991.46 18.86 -77.27 971.50 985.87 64.01 33.23 67.78 119.49 15.49 104.01 PASS 1 1100.001- 1085.28 27.06 -110.85 106538 1078.80 77.27 32.67 70.72 152.19 16.28 135.90 PASS E 1200.001- 1176.69 36.67 -150.20 115735 1169.66 91.49 31.88 73.24 190.28 17.12 173.16 PASS 1300.001- 1265.31 47.65 -195.17 1246.27 1257.27 106.66 30.80 75.36 233.68 17.97 215.70 PASS 1400.001- 1350.78 59.95 -245.56 1332.04 1341.54 122.63 29.88 77.18 282.64 18.86 263.78 PASS 1500.001- 1432.75 73.53 -301.18 1415.51 1423.27 139.50 28.80 78.70 336.64 19.78 316.86'PASS_ 1600.001- 1510.88 88.33 -361.79 1494.07 1499.85 157.00 27.70 80.00 395.65 20.72 374.94 PASS 1700.001- 1584.84 104.29 -427.15 1569.40 1572.86 175.54 26.62 81.08 459.48 21.71 437.78 PASS 1800.001- 1654.34 12133 -496.97 1638.63 1639.51 194.20 25.62 82.06 527.86 22.66 505.20 PASS 1 1888.30 1711.77 137.24- -562.12 1694.42 1692.88 210.45 25.09 82.89 592.06 23.52 568.54 PASS 1900.001- 1719.12 139.40 -570.96 1702.02 1700.13 212.74 25.04 82.98 600.80 23.65 577.15 PASS 2000.001- 1781.99 157.84 -646.51 1763.22 1759.14 228.89 24.85 83.96 675.49 24.49 651.01 PASS 2013.00 1790.16 160.24 -656.33 1769.50 1765.24 230.42 24.90 84.12 685.29 24.46 660.83 PASS i 2100.001- 1846.57 175.66 -720.74 1826.40 1820.51 243.92 25.43 84.77 749.73 25.22 724.52 PASS 2200.001- 1915.50 191.80 -791.34 189858 1890.85 260.07 26.29 85.23 820.85 26.15 794.70 PASS 2300.001- 1988.58 206.19 -858.05 1972.73 1963.45 275.14 27.18 85.55 888.27 27.08 861.19 PASS 2400.001- 2065.55 218.77 -920.61 2059.65' 2048.89 291.08 27.83 85.64 951.34 28.11 923.23 PASS 2410.70 2074.00 220.01 -927.05 2068.44 2057.56 292.56 27.87 85.66 957.81 28.19 929.62 PASS € €9 15 • 0 cell Clearance Report FA Ili Olson 2 Ver#4 BAKER Cook Inlet Energy_ Closest Approach Page 4 of 25 HUGHES REFERENCE WELLPATH IDENTIFICATION t. _ Operator Cook Inlet Energy _ - _. _ _- Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 ,Field n field Olson Creek Unit Wellbore Olson 2 WellPla Facility Olson Creek , CLEARANCE DATA-Offset Wellbore:Olson 1 Offset Wellpath:Olson 1 Facility:Olson Creek Slot:Olson 1 Slot Welt Olson 1 Threshold Value=0.00 ft t=interpolated/extrapolated statim Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Horiz C-C ACR Ellipse ACR [R] [R] [ft] 011 [R] 81] [ft] 61] Bearing Clear Dist MASD Sep Status Pl RI _[n] PI i 2420.90 j 2082.06 221.19 -933.19 2076.14 2065.15 293.84 27.90 85.68 963.98 28.27 935.71 PASS 2500.00 2144.45 230.32 -980.95 2136.32 2124.57 303.36 28.34 85.86 1012.12 28.86 983.25 PASS 2600.00 2223.33 241.87 -1041.32 2212.71 2200.13 314.49 29.07 86.12 1073.10 29.61 1043.49 PASS r 2700.00 2302.21 2.53.42 -1101.70 2292.99 2279.87 323.75 30.15 86.44 1134.25 3034 1103.91 PASS 2600.001 2381.08 264.97 -1162.07 2377.17 2363.74 330.85 31.10 86.84 1195.11 31.04 1164.07 PASS 2900.00t 2459.96 276.52 -1222.45 2456.07 2442.48 335.67 32.01 87.30 1255.97 31.63 1224.35 PASS 3000.00} 2538.83 288.07 -1282.82 2541.14 2527.51 338.46 32.86 87.81 1316.69 32.19 1284.50 PASS 3100.00} 2617.71 299.62 -1343.20 2615.46 2601.82 338.71 33.52 88.37 137736 32.61 1344.75 PASS 3200.00} 2696.59 311.17 -1403.57 2688.72 2675.06 337.46 34.49 88.95 1438.47 32.98 1405.49 PASS 3300.001 2775.46 322.72 -1463.95 2765.27 2751.57 335.36 35.72 89.52 149991 33.35 1466.56 PASS I 3400.001- 2854.34 334.27 -1524.32 2847.69 2833.96 333.25 36.92 90.04 156137 33.77 1527.60 PASS 3500.001 2933.22 345.82 -1584.70 2925.22 2911.46 331.40 37.99 90.51 1622.89 34.18 1588.71 PASS 3600.001 3012.09 357.37 -1645.07 3011.72 2997.93 329.50 38.89 90.95 168425 34.67 1649.57 PASS 3700.001 3090.97 368.92 -1705.45 3092.02 3078.21 327.97 39.48 91.34 1745.46 35.15 1710.31 PASS 3800.001 3169.84 380.47 -1765.82 3167.01 3153.19 326.75 40.07 91.70 1806.77 35.61 1771.16 PASS 3900.001 3248.72 392.02 -1826.20 3248.72 3234.89 325.60 40.74 92.04 1868.17 36.13 1832.04 PASS 4000.001 3327.60 403.57 -1886.57 3330.99 3317.15 324.65 41.22 92.34 1929.44 36.68 1892.76 PASS 4100.001 3406.47 415.12 -1946.95 3411.00 3397.16 323.78 41.58 92.63 1990.64 37.23 1953.42 PASS 4200.001 3485.35 426.67 -2007.32 3489.98 3476.13 323.04 41.90 92.90 2051.86 37.78 2014.08 PASS 4300.001 3564.23 438.22 -2067.70 3568.59 3554.74 322.44 42.22 93.14 2113.11 38.35 2074.77 PASS 4400.001 3643.10 449.77 -2128.07 3647.54 3633.68 322.01 42.56 93.37 2174.41 38.93 2135.48 PASS 4500.001 3721.98 461.32 -2188.45 3730.92 3717.07 321.69 42.82 93.58 2235.64 39.56 2196.07 PASS 4600.001 3800.85 472.87 -2248.82 3817.44 3803.58 321.58 42.85 93.78 2296.66 40.24 2256.42 PASS 4700.001 3879.73 484.42 -2309.20 3900.15 3886.29 321.58 42.69 93.96 235752 40.89 2316.63 PASS 4800.001- 3958.61 495.97 -2369.57 3980.08 3966.23 321.72 42.46 94.13 241833 41.54 2376.79 PASS 4900.001 4037.48 507.52 -2429.95 4069.11 4055.25 322.14 42.05 94.29 2479.00 42.27 2436.72 PASS 5000.00} 4116.36 519.07 -2490.32 4161.57 4147.71 322.74 41.19 94.44 253931 43.05 2496.26 PASS 5100.00, 4195.24 530.62, -2550.70 4242.46 4228.59 323.41 40.20 94.57 259939 43.74 2555.65 PASS 5200.001` 4274.11 542.17 -2611.07 4322-914309.03[ 324.18 39.22 94.70 2659.47 44.43 2615.04 PASS 5300.001 4352.99 553.72 -2671.45 4397.92 4384.03 324.68 38.31 94.83 2719.60 45.07 2674.52 PASS €a 16 I • 0 ceB Clearance Report 113110111 Cook Inlet Ener Olson 2 rBAKER - - Energy CbsestApproach Page 5 of 25 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot 'Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek CLEARANCE DATA-Offset Wellbore:Olson 1 Offset Weupath:Olson 1 Facility:Olsm Creek Slot:Olson 1 Slot Welt Olson 1 Threshold Value=0A0 ft t=Interpolated/extrapolated statim Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Horn C-C ACR Ellipse ACR [R] [Ill [ft] Rt] [R] pt] [(t] [it] Bearhg Clear Dist MASD Sep Status rl RI [n] [it] 5400.00} 4431.86 565.27 -2731.82 4465.60 4451.71 324.55 37.64 94.97 2779.97 45.65 2734.32 PASS 5500.00} 4510.74 576.82 -2792.20 4526.87 4512.98 323.9637.34 95.11 2840.81 46.16 2794.65 PASS 5600.00} 4589.62 588.37 -2852.57 4603.53 4589.62 322.89 37.22 95.25 2901.96 46.80 2855.17 PASS 5700.00}+ 4668.49 599.92 -2912.95 4685.99 4672.08 321.70 37.08 95.39 2963.11 47.49 2915.63 PASS 5800.0ot 4747.37 611.47 -2973.32 4768.02 4754.10 320.58 36.82 95.52 3024.17 48.19 2975.98 PASS 5900.00} 4826.25 623.02 -3033.70 4851.96 4838.03 319.55 36.48 95.65 3085.16 48.91 3036.25 PASS 6000.001- 4905.12 634.57 -3094.07 4932.01 4918.07 318.48 36.02 95.77 3146.04 49.61 3096.43 PASS 6100.00} 4984.00 646.12 -3154.45 5010.04 4996.10 317.42 35.62 95.88 3206.98 50.29 3156.69 PASS 6200.00} 5062.87 657.67 -3214.82 5095.40 5081.44 316.40 35.13 95.99 3267.88 51.04 3216.84 PASS 6300.00} 5141.75 669.22 -3275.20 5160.00 5146.04 315.64 34.59 96.10 3328.62 51.63 3277.00 PASS 6400.00} 5220.63 680.77 -3335.57 5160.00 5146.04 315.64 34.59 96.18 3390.71 51.67 3339.04 PASS 6500.00} 5299.50 692.32 -3395.95 5160.00 5146.04 315.64 34.59 96.27 3454.57 51.69 3402.87 PASS 6600.00} 5378.38 703.87 -3456.32 5160.00 5146.04 315.64 34.5996.35 3520.111 51.71' 3468.40 PASS 6700.00} 5457.25 715.42 -3516.70 5160.00 5146.04 315.64 34.59 96.42 3587.24 51.71 3535.53 PASS 6800.00} 5536.13 726.97 -3577.07 5160.00 5146.04 315.64 34.59 96.50 3655.88 51.71 3604.17 PASS 6900.00} 5615.01 738.52 -3637.44 5160.00 5146.04 315.64 34.59 96.57 372594 51.70 3674.24 PASS 7000.00} 5693.88 750.07 -3697.82 5160.00 5146.04 315.64 34.59 96.64 379734 51.68 3745.65 PASS 7100.00} 5772.76 761.62 -3758.19 5160.00 5146.04 315.64 34.59 96.71 3870.00 51.67 3818.33 PASS 7200.00} 5851.64 773.17 -3818.57 5160.00 5146.04 315.64 34.59 96.77 3943.86 51.65 3892.22 PASS 7300.00} 5930.51 784.72 -3878.94 5160.00 5146.04 315.64 34.59 96.84 4018.86 51.63 3967.23 PASS 7400.00} 6009.39 796.27 -3939.32 5160.00 5146.04 315.64 34.59 96.90 4094.92 51.61 4043.31 PASS 7446.50 6046.07 801.64 -3967.39 5160.00 5146.04 315.64 34.59 96.92 4130.63 51.60 4079.04 PASS 7500.00} 6088.72 807.69 -3999.11 5160.00 5146.04 315.64 34.59 96.96 4171.52 51.58 4119.93 PASS 7600.00} 6170.80 818.31 -4055.22 5160.00 5146.04 315.64 34.59 97.01 4246.10 51.46 4194.64 PASS 7700.00} 6255.76 828.01 -4107.05 5160.00 5146.04 315.64 34.59 97.05 4318.24 51.41 4266.83 PASS 7777.90 6323.78 834.90 -4144.37 5160.00 5146.04 315.64 34.59 97.08 4372.69 51.34 4321.34 PASS 7800.00} 6343.29 836.77 -4154.57 5160.00 5146.04 315.64 34.59 97.09 4387.95 51.32 4336.63 PASS 7900.001- 6431.60 845.24 -4200.73 5160.00 5146.04 315.64 34.59 97.13 4457.70 51.19 4406.51 PASS 8000.00} 6519.90 853.72 -4246.89 5160.00 5146.04 315.64 34.59 97.16 4528.59 51.08 4477.51 PASS 8100.00} 6608.20 862.19 -4293.05 5160.00 5146.04 315.64 34.59 97.20 4600.56 50.97 4549.59 PASS €1 17 0 • eea Clearance Report IMO Olson 2r BAKER _ Cook Inlet Energy_ Closest Approach Page 6 of 25 HUGHES * .x'' '` , IDENTIFICATION Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPian Facility Olson Creek CLEARANCE DATA-Offset Wellbore:Olson 1 Offset Weliputh:Olson 1 Facility:Oism Creek Slot:Olson 1 Slot Welt Olson 1 Threshold Value=0.00 ft t=interpolated/extrapolated statim Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Boric C-C ACR Ellipse ACR Ertl [rt] [R] [n] [ft] [ft] [it] [R] Bearing Clear Dist MASD Sep Status 1°] lit] [rt1 P1 8200.001 6696.51 870.66 -4339.21 5160.00 5146.04 315.6434.59 97.23 467336 50.87 4622.69 PASS 8300.001 6784.81 879.13 -438537 5160.00 5146.04 315.64 34.59 9727 4747.54 50.78 4696.77 PASS 8400.001 6873.11 887.60 -443133 5160.00 5146.04 315.64 34.59 9730 4822.47 50.69 4771.78 PASS 8500.001 6961.41 896.08 -4477.69 5160.00 5146.04 315.64 34.59 9733 4898.29 50.62 4847.67 PASS 8600.001 7049.72 904.55 -4523.86 5160.00 5146.04 315.64 34.59 9736 497496 50.55 4924.41 PASS'': 8700.001 7138.02 913.02 -4570.02 5160.00 5146.04 315.64 34.59 9739 5052.45 5030 5001.96 PASS€ 8800.001 7226.32 921.49 -4616.18: 5160.00 5146.04 315.64 34.59 97.42 5130.72 50.45 5080.27 PASS 8900.001 7314.63 929.96 -4662341 5160.00 5146.04 315.64 34.59 97.45 5209.73 50.41 5159.32 PASS 9000.001 7402.93 938.44 -470830 5160.00 5146.04 315.64 34.59 97.48 5289.45 5039 5239.07 PASS g 9100.001 7491.23 946.91 -4754.66 5160.00 5146.04 315.6434.59 9731 5369.86 5037 5319.48 PASS'1 9200.001 7579.54 955.38 -4800.82 5160.00 5146.04 315.64 34.59 9734 5450.91 5037 5400.54 PASS 9300.001 7667.84 963.85 -4846.98 5160.00 5146.04 315.64 34.59 9756 553238 5038 5482.20 PASS 9400.001 7756.14 97232 -4893.14 5160.00 5146.04 315.64 34.59 9759 5614.84 5039 5564.45 PASS 9500.001 7844.44 980.80 -493930 5160.00 5146.04 315.64 34.59 97.62 5697.67 50.42 5647.25 PASS 9600.001 7932.75 989.27 -4985.46 5160.00 5146.04 315.64 34.59 97.64 5781.04 50.46 5730.58 PASS I 9700.001 8021.05 997.74 -5031.62 5160.00 5146.04 315.64 34.59 97.67 5864.94 50.51 5814.42 PASS 1 9800.001 8109.35 1006.21 -5077.78 5160.00 5146.04 315.64 34.59 97.69 594933 50.57 5898.75 PASS 9900.001 8197.66 1014.68 -5123.95 5160.00 5146.04 315.64 34.59 97.72 6034.20 50.65 5983.55 PASS I 10000.001 8285.96 1023.16 -5170.11 5160.00 5146.04 315.64 34.59 97.74 611932 50.73 6068.79 PASS 10100.001 8374.26 1031.63 -521627 5160.00 5146.04 315.64 34.59 97.77 620529 50.82 6154.46 PASS 10200.001 8462.56 1040.10 -5262.43 5160.00 5146.04 315.64 34.59 97.79 6291.47 5093 6240.54 PASS 10300.001 8550.87 1048.57 -530839 5160.00 5146.04 315.64 34.59 97.81 6378.06 51.04 6327.01 PASS 10400.001 8639.17 1057.05 -5354.751 5160.00 5146.04 315.64 34.59 97.83 6465.03 51.17 6413.86 PASS I 10500.001 8727.47 1065.52 -5400.91 5160.00 5146.04 315.64 34.59 97.86 655238 5131 6501.07 PASS I 10600.001 8815.78 1073.99 -5447.07 5160.00 5146.04 315.64 34.59 97.88 6640.08 51.45 6588.63 PASS I 10700.001 8904.08 1082.46 -5493.23 5160.00 5146.04 315.64 34.59 9790 6728.13 51.61 6676.51 PASS 10800.001 8992.38 1090.93 -553939 5160.00 5146.04 315.64 34.59 9792 681650 51.78 6764.72 PASS 10900.001 9080.69 1099.41 -558535 5160.00 5146.04 315.64 34.59 97.94 6905.20 51.96 6853.24 PASS 11000.001 9168.99 1107.88 -5631.71 5160.00 5146.04 315.64 34.59 97.96 6994.19 52.15 6942.05 PASS 11100.001 9257.29 1116.35 -5677.87 5160.00 5146.04 315.64 34.59 9798 7083.49 5235 7031.14 PASS €6 18 • • aB Clearance Report iI Olson2 rBAKER _ Cook Inlet Energy_ ClosestsestApproach Page 7 of 25 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek CLEARANCE DATA-Offset Wellbore:Olson 1 Offset Weupath:Olson 1 Facility:Olson Creek Slot:Olson 1 Slat Welk Olson 1 Threshold Value=0.00 ft t=interpolated/extrapolated station Ref MD Ref TVD Rel North Ref East Offset MD Offset TVD Offset North Offset East Hark C-C ACR Ellipse ACR [ft] [ft] [ft] [ft] [ft] [R] [ft] [ft] Bearing Clear Dist MASD Sep Status 1°] lit] [ft] [ft] 11200.001. 9345.59 1124.82 -5724.03 5160.00 5146.04 315.64 34.59 98.00 7173.06 52.55 7120.51 PASS 11300.001. 9433.90 1133.29 -5770.20 5160.00 5146.04 315.64 34.59 98.02 7262.91 52.77 7210.14 PASS 11400.001. 9522.20 1141.77 -5816.36 5160.00 5146.04 315.64 34.59 98.04 7353.02 53.00 7300.02 PASS 11500.00f 9610.50 1150.24 -5862.52 5160.00 5146.04 315.64 34.59 98.06 7443.38 53.24 7390.14 PASS 11600.001. 9698.81 1158.71 -5908.68 5160.00 5146.04 315.64 34.59 98.07 7533.98 53A8 7480.50 PASS' 11700.001. 9787.11 1167.18 -5954.84 5160.00 5146.04 315.64 34.59 98.09 7624.82 53.74 7571.08 PASS j 11800.001. 9875.41 1175.65 -6001.00 5160.00 5146.04 315.64 34.59 98.11 7715.89 54.00 7661.89 PASS 1 1 11900.001. 9963.72 1184.13 -6047.16 5160.00 5146.04 315.64 34.59 98.13 7807.17 54.28 7752.90 PASS 11967.90 10023.67 1189.88 -6078.50 5160.00 5146.04 315.64 34.59 98.14 7869.28 54.47 7814.81 PASS POSITIONAL UNCERTAINTY- Offset Wellbore:Olson 1 Offset Wellpath:Olson 1 Slot Surface Uncertainty @1SD Horizontal 2.000ft Vertical 1.000ft - Facility Surface Uncertainty @1 SD Horizontal 20.000ft Vertical 3.000ft - HOLE&CASING SECTIONS-Offset Wellbore:Olson 1 Offset Wellpath:Olson 1 String/Diameter Start MD End MD Interval Start TVD End TVD StartN/S Start EJW End N/S End ENV [n] [ft] [n] [n] [n] [n] [n] [ft] [ft] 110.75in Conductor 15.30 157.00 141.70 48.10 189.78 -3.35 18.89 -2.70 18.90 [7.625in Casing �� 15.30 1600.00 1584.70 48.10 1617.67 -3.35 18.89 54.28 17.42 [6.75in Open Hole 15.30 1600.00 1584.70 48.10 1617.67 -3.35 18.89 54.28 17.42 16.75in Open Hole 1600.00 5643.00 4043.00 1617.67 NA 54.28 17.42 NA NA €5 19 cell Clearance Report FARM Olson 2Ver#4BAKER Cook Inlet Energy Closest Approach Page 8 of 25 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPian Facility Olson Creek WELLPATH COMPOSITION-Offset Wellbore:Olson 1 Offset Wellpath:Olson 1 Start MD End MD Positional Uncertainty Model Log Name/Comment Wellbore [[t] [ft] 15.30 1600.00 Generic gyro-continuous(Standard) Olson 1 PB1 Gyro<0-1850> Olson 1 PB1 1600.00 5160.00 ISCWSA MWD,Rev.2,axial magnetic correction(Standard) Olson 1 Olson 1 OFFSET WELLPATH MD REFERENCE- Offset Wellborn:Olson 1 Offset Wdlpath:Olson 1 MD Reference:Rig on Olson 1(RKB) rOffiet TVD&local coorcanates use Reference Wellpath settings (&e WBLLPATHDATUMonpage 1 of this report) Ellipse Start MD .339.7011 €1 20 . • o:13 Clearance Report Valli" Olson 2`'e'er` BAKER Cook Inlet Energy Cbro Closest Page 9 of 25 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek CLEARANCE DATA-Offset Wein)ore:Olson 1 PB1 Offset Wellpath:Olson 1 PB1 Facility:Olsm Creek Slot:Okra 1 Slot Welt Olson 1 PB1 Threshold Value=0.00 ft }=itterp olated/extrapolated station Ref MI) Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Horiz C-C ACR Ellipse ACR [ft] [ft] [ft] [ct] [rt] [ft] [ft] [ft] Bearing Clear Dist MASD Sep Status [°] [ft] [ft] [ft] 0.00 0.00 0.00 0.00 1530 32.80 -5.49 30.99 100.05 45.46 1.01 44.45 PASS 100.001- 100.00 0.00 0.00 8258 100.08 -5.04 30.98 99.24 31.39 1.01 30.38 PASS 200.001- 200.00 0.00 0.00 18236 200.02 -2.48 31.05 94.56 31.15 0.88 30.28 PASS 205.001- 205.00 0.00 0.00 18730 204.96 -2.28 31.07 94.20 31.15 0.72 30.43 PASS 300.001- 300.00 0.00 0.00 282.43 299.78 2.17 3138 86.05 31.45 0.72 30.73 PASS 400.001- 400.00 0.00 0.00 382.16 399.35 7.83 31.80 76.16 32.76 11.65 21.11 PASS 417.901- 417.90 0.00; 0.00 400.00 417.15 8.95 31.90 74.33 33.14 12.72' 20.41 PASS 500.00 500.00 0.00 0.00 481.79 498.76 14.50 3236 65.87 35.48 12.75 22.74 PASS I 600.001- 599.93 0.76 -3.12 581.29 597.95 22.22 32.93 59.24 42.00 12.93 29.07 PASS (I 700.001- 699.45 3.04 -12.45 68039 696.67 30.89 33.44 58.75 53.75 13.44 40.31 PASS I 800.001- 798.15 6.83 -27.97 778.67 794.46 40.66 33.69 61.25 70.43 14.12 56.31 PASS 900.001- 895.62 12.11 -49.60 875.84 891.00 51.74 33.61 64.53 92.28 14.72 77.56 PASS 1000.001- 991.46 18.86 -77.27 97130 985.87 64.01 3323 67.78 119.49 15.49 104.01 PASS 1100.001- 1085.28 27.06 -110.85 106538 1078.80 77.27 32.67 70.72 152.19 16.28 135.90 PASS 1200.001- 1176.69 36.67 -150.20 115735 1169.66 91.49 31.88 73.24 190.28 17.12 173.16 PASS 1300.001- 1265.31 47.65 -195.17 124627 1257.27 106.66 30.80 75.36 233.68 17.97 215.70 PASS 1400.001- 1350.78 59.95 -245.56 1332.04 1341.54 122.63 29.88 77.18 282.64 18.86 263.78 PASS 1500.001- 1432.75 73.53 -301.18 141531 1423.27 139.50 28.80 78.70 336.64 19.78 316.86 PASS 1600.001- 1510.88 88.33 -361.79 1494.07 1499.85 157.00 27.70 80.00 395.65 20.72 374.94 PASS I 1700.001- 1584.84 104.29 -427.15 1569.40 1572.86 175.54 26.62 81.08 459.48 21.71 437.78 PASS 1800.001- 1654.34 121.33 -496.97 1639.66 1640.50 194.49 2556 82.03 527.82 22.74 505.08 PASS I 1888.30 1711.77 137.24 -562.12 169725 1695.58 211.30 24.82 82.81 591.82 23.68 568.14 PASS 1900.001- 1719.12 139.40 -570.96 1704.61 1702.59 213.53 24.73 82.91 600.52 23.81 576.71 PASS 2000.001- 1781.99 157.84 -646.51 1767.03 1761.77 233.36 24.10 83.58 675.16 24.82 650.34 PASS 2013.00 1790.16 160.24 -656.33 1775.10 1769.39 236.04 24.03 83.64 684.89 24.84 660.05 PASS 2100.001- 1846.57 175.66 -720.74 1830.72 1821.59 255.22 23.62 83.90 749.02 25.78 723.24 PASS 2200.001. 1915.50 191.80 -791.34 1898.12 1884.26 280.01 23.21 83.82 819.91 26.93 792.99;PASS 2300.001- 1988.58 206.19 -858.05 196791( 1948.38 307.56 22.82 83.44 887.60 28.14 859.46.PASS 2400.001- 2065.55 218.77 -920.61 2039.631 2013.39 337.83 22.46 82.81 951.99 29.37 922.62 PASS 2410.70 2074.00 220.01 -927.05 2048.62 2021.50 341.73 22.41 82.70 958.67 29.52 929.15 PASS €2 21 • • cell Clearance Report Fail. ° 2 vee BAKER _ Cook Inlet Energy Closest Approach Page 10 of 25 HVGIIES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot 'Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek CLEARANCE DATA-Offset Wellbore:Olson 1 PB1 Offset Wellpath:Olson 1 PB1 Facility:Okm Creek Slot:Olson 1 Slot Welt Olson 1 PB1 Threshold Value=0.00 ft t=interpolated/extrapolated station Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Horn C-C ACR Ellipse ACR [it] [ft] in] Pn] [ft] pt] Eft] 8t] Bearttg Clear Dist MASD Sep Status P] [ft] [ft] Pt] 2420.90 2082.06 221.19 -933.19 2057.21 2029.24 345.44 22.36 82.59 965.04 29.67 935.37 PASS 2500.00{ 2144.45 230.32 -980.95 2131.48 2096.60 376.69 21.56 81.69 101426 30.99 983.27 PASS 2600.00j 2223.33 241.87 -1041.32 2218.11 2176.34 410.51 19.92 80.97 1075.59 32.58 1043.01 PASS 2700.001- 2302.21 253.42 -1101.70 2313.11 2264.88 444.88 17.71 80.30 1136.27 34.38 1101.89 PASS 2800.001- 2381.08 264.97 -1162.07 2407.16 2353.72 475.57 14.85 79.86 119593 36.14 1159.79 PASS 2900.001- 2459.96 276.52 -1222.45 2501.22 2443.43 503.63 11.31 79.57 125459 37.87 1216.72 PASS 3000.001- 2538.83 288.07 -1282.82 2590.06 2528.79 527.98 7.79 79.47 1312.76 39.45 1273.31 PASS 3100.001- 2617.71 299.62 -1343.20 2677.61 2613.62 549.36 4.21 79.50 137036 40.92 1329.44 PASS 3200.001- 2696.59 311.17 -1403.57 2768.78 2702.59 568.88 0.64 79.60 1427.68 42.35 1385.33 PASS 3300.001- 2775.46 322.72 4463.95 2861.17 2793.33 585.83 -3.23 79.79 148433 43.67 1440.66 PASS 3400.001- 2854.34 334.27 -1524.32 2956.81 2887.68 600.60 -7.59 80.03 154033 44.93 1495.40 PASS 3500.001- 2933.22 345.82 -1584.70 3050.15 2980.10 613.05 -12.13 80.36 1595.80 46.05 1549.75 PASS 3600.001- 3012.09 357.37 -1645.07 3125.59 3055.02 621.22 -15.69 80.80 1651.16 46.88 1604.28 PASS 3700.001- 3090.97 368.92 -1705.45 3200.11 3129.20 627.56 -18.50 81.28 1707.09 47.61 1659.48 PASS 3800.001- 3169.84 380.47 -1765.82 3275.13 3204.05 632.14 -20.72 81.79 1763.49 48.24 1715.25 PASS 3900.001- 3248.72 392.02 -1826.20 3346.74 3275.62 633.89 -22.33 82.36 1820.20 48.71 1771.49 PASS 4000.00t 3327.60 403.57 -1886.57 3425.73 3354.60 634.07 -23.59 82.95 187738 49.14 1828.25 PASS 4100.001- 3406.47 415.12 -1946.95 3505.71 3434.56 632.67 -24.60 83.54 1934.82 49.49 1885.34 PASS 4200.00t 3485.35 426.67 -2007.32 3592.58 3521.35 629.24 -25.92 84.16 1992.06 49.78 1942.27 PASS 4300.001- 3564.23 438.22 -2067.70 3662.70 3591.37 62.5.78 -26.77 84.75 2049.70 50.00 1999.70 PASS 4400.001- 3643.10 449.77 -2128.07 3735.59 3664.16 621.94 -27.36 85.32 2107.86 50.21 2057.65 PASS 4500.001- 3721.98 461.32 -2188.45 3800.32 3728.77 617.98 -27.52 85.85 2166.61 50.39 2116.22 PASS 4600.001- 3800.8.5 472.87 -2248.82 3887.74 3815.98 611.95 -27.62 86.42 2225.60 50.60 2174.99 PASS 4700.001- 3879.73 484.42 -2309.20 3973.15 3901.20 606.17 -28.06 86.95 2284A8 50.84 2233.64 PASS 4800.001- 3958.61 495.97 -2369.57 4052.73 3980.59 600.75 -28.50 87.44 2343.51 51.08 2292.43 PASS 4900.00t 4037.48 507.52 -2429.95 4131.14 4058.81 595.29 -29.00 87.91 2402.64 51.32 2351.32 PASS 5000.001- 4116.36 519.07 -2490.321 4215.61 4143.09 589.61 -29.62 88.36 2461.85 51.62 2410.24 PASS 5100.001- 4195.24 530.62 -2550.70 4298.67 4225.97 584.23 -30.46 88.78 2520.99 51.93 2469.06 PASS 5200.001- 4274.11 542.17 -2611.07 4390.65 4317.74 578.24 -31.63 89.20 2580.06 52.28 2527.78 PASS 5300.001- 4352.99 553.72 -2671.45 4479.68 4406.59 572.74 -33.28 89.59 2638.78 52.66 2586.12 PASS;a €P 22 0 ceB Clearance Report FARO Olson 2r BAKER _ Cook Inlet Energy_ Closest Approach Page 11 of 25 HES REFERENCE A ELLPATH IDENTIFICATION ., Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek CLEARANCE DATA-Offset Wellbore:Olson 1 PB1 Offset Wellpath:Olson 1 PB1 Facility:Olson Creek Slot:Olson 1 Slat Welt Olson 1 PB1 Threshold Value=0.00 It t=inter'olated/extrapolated station Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset Ninth Offset East Horn C-C ACR Ellipse ACR [R] [ft] pt] 8t] [it] 8t] [rt] [Pt] Bearing Clear Dist MASD Sep Status M DI" [It] lit] 5400.00} 4431.86 565.271 -2731.82 4569.04 4495.76 567.34 -35.19 89.96 269739 53.07 2644.32 PASS 5500.00} 4510.74 576.82 -2792.20 4640.88 4567.46 563.09 -36.89 90.29 2755.92 53.41 2702.51 PASS 5600.00} 4589.62 588.37 -2852.57 4727.06 4653.46 557.87 -38.75 90.62 2814.71 53.83 2760.88 PASS 5700.00} 4668.49 599.92 -2912.95 4828.30 4754.47 551.69 -41.56 90.96 2873.07 54.33 2818.75 PASS 5800.00} 4747.37 611.47 -2973.32 4905.66 4831.63 546.70 -43.91 91.27 293133 54.72 2876.62 PASS 5900.00} 4826.25 623.02 -3033.70 5008.83 4934.53 540.05 -47.49 91.59 298932 55.24 2934.08 PASS 6000.00} 4905.12 634.57 -3094.07 5089.39 5014.84, 534.571 -50.55 91.88 3047.14 55.67 2991.47 PASS [ 6100.00} 4984.00 646.12 -3154.45 5183.44 5108.58` 527.92r -54.33 92.18 3104.86 56.16 3048.70 PASS 6200.00} 5062.87 657.67 -3214.82 5288.16 5212.91 520.43 -59.31 92.49 3162.05 56.73 3105.32 PASS 6300.00} 5141.75 669.22 •3275.20 5377.49 5301.89 513.96 -63.86 92.77 3219.07 57.24 3161.83 PASS 6400.00} 5220.63 680.77 -3335.57 5477.89 5401.86 506.64 -69.64 93.05 327559 57.81 3217.77 PASS 6500.001. 5299.50 692.32 -3395.95 5533.00 5456.73 502.61 -72.87 93.27 333220 58.17 3274.03 PASS I 6600.00} 5378.38 703.87 -3456.32 5533.00 5456.73 502.61 -72.87 93.40 339034 58.23 3332.11 PASS 6700.001- 5457.25 715.42 -3516.70 5533.00 5456.73 502.61 -72.87 93.54 345039 58.26 3392.13 PASS 6800.001. 5536.13 726.97 -3577.07 5533.00 5456.73 502.61 -72.87 93.66 3512.27 58.28 3453.99 PASS j 6900.00} 5615.01 738.52 -3637.44 5533.00 5456.73 502.61 -72.87 93.79 3575.88 58.29 3517.59 PASS 7000.00} 5693.88 750.07 -3697.82 5533.00 5456.73 502.61 -72.87 93.91 3641.12 58.28 3582.84 PASS 7100.001. 5772.76 761.62 -3758.19 5533.00 5456.73 502.61 -72.87 94.02 3707.91 58.26 3649.65 PASS 7200.001- 5851.64 773.17 -3818.57 5533.00 5456.73 502.61 -72.87 94.13 3776.17 58.23 3717.93 PASS 7300.001- 5930.51 784.72 -3878.94 5533.00 5456.73 502.61 -72.87 94.24 3845.81 58.20 3787.62 PASS i t7400.00} 6009.39 796.27 -3939.32 5533.00 5456.73 502.61 -72.87 94.34 3916.77 58.15 3858.62 PASS 7446.50 6046.07 801.64 -3967.39 5533.00 5456.73 502.61 -72.87 94.39 3950.20 58.13 3892.06 PASS 1 7500.00} 6088.72 807.69 -3999.11 5533.00 5456.73 502.61 -72.87 94.44 3988.47 58.10 3930.36 PASS 7600.00} 6170.80 818.31 -4055.22 5533.00 5456.73 502.61 -72.87 94.53 4058.16 57.95 4000.21 PASS 7700.001. 62.55.76 828.01 -4107.05 5533.00 5456.73 502.61 -72.87 94.61 4125.40 57.86 4067.54 PASS 7777.90 6323.78 834.90 -4144.37 5533.00 5456.73 502.61 -72.87 94.67 4176.04 57.76 4118.28 PASS 7800.00} 6343.29 836.77 -4154.57 5533.00 i 5456.73 502.61 -72.87 94.68 419022 57.73 4132.49 PASS 1. 7900.00} 6431.60 845.24 -4200.73 5533.00 5456.73 502.61 -72.87 94.75 425523 57.56 4197.68 PASS I-8000.00f 6519.90 853.72 -4246.89 5533.00 5456.73 502.61 -72.87 94.81 432158 57.39 4264.19 PASS 8100.001. 6608.20 862.19 -429105 5533.00 5456.73 502.61 -72.87 94.87 438921 57.22 4331.98 PASS €1 23 • 0 cell Clearance Report Irfi'd111 Cook_Inlet EnergyOlson2 rBAKER - Cbsestest Approach Page 12 of 25 HUGHES err 17 . ,. WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot Olson 2 Slot '_Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek CLEARANCE DATA-Offset Wellbore:Olson 1 PBI Offset Wellpath:Olson 1 PB1 Facility:Okm Creek Slat:Olsen 1 Slot Well Olson 1 PD1 Threshold Value=0.00 it t=interpolated/extrapolated station Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Rork C-C ACR Ellipse ACR 8t] Rt] [ft] Itt] [ft] [ft] [ft) [ft] Bearing Clear Dist MASD Sep Status 19 [it] [n] [ft] 8200.001- 6696.51 870.66 -4339.21 5533.00 5456.73 502.61 -72.87 94.93 4458.05' 57.06 4400.98 PASS 8300.00} 6784.81 879.13 -438537 5533.00 5456.73 502.61 -72.87 94.99 4528.05 56.91 4471.14 PASS 8400.00} 6873.11 887.60 -443153 5533.00 5456.73 502.61 -72.87 95.05 4599.17 56.76 4542.40 PASS 8500.00} 6961.41 896.08 -4477.69 5533.00 5456.73 502.61 -72.87 95.10 467134 56.62 4614.72 PASS 8600.001- 7049.72 904.55 -4523.86 5533.00 5456.73 502.61 -72.87 95.16 474452 56.49 4688.03 PASS 8700.00} 7138.02 913.02 -4570.02 5533.00 5456.73 502.61 -72.87 95.21 4818.66 56.36 4762.30 PASS 8800.001- 7226.32 921.49 -4616.18 5533.00 5456.73 502.61 -72.871 9527 4893.73 56.25 4837.48 PASS 8900.00} 7314.63 929.96 -466234 5533.00 5456.73 502.61 72.87. 9532T 4969.67 56.14 4913.531 PASS. 9000.001- 7402.93 938.44 -470850 5533.00 5456.73 502.61 -72.87 9537 5046.46 56.04 4990.41 PASS 9100.001- 7491.23 946.91 -4754.66 5533.00 5456.73 502.61 -72.87 95.42 5124.04 5595 5068.09 PASS 9200.00} 7579.54 955.38 -4800.82 5533.00 5456.73 502.61 -72.87 95.47 520239 55.88 5146.51 PASS 9300.001- 7667.84 963.85 -4846.98 5533.00 5456.73 502.61 -72.87 9.552 5281.47 55.81 5225.66 PASS 9400.00} 7756.14 972.32 -4893.14 5533.00 5456.73 502.61 -72.87 9557 5361.25 55.75 5305.49 PASS 9500.00} 7844.44 980.80 -493930 5533.00 5456.73 502.61 -72.87 95.61 5441.69 55.71 5385.99 PASS 9600.001- 7932.75 989.27 -4985.46 5533.00 5456.73 502.61 -72.87 95.66 5522.78 55.67 5467.11 PASS 9700.00} 8021.05 997.74 -5031.62 5533.00 5456.73 502.61 -72.87 95.70 5604.48 55.65 5548.83 PASS 9800.00} 8109.35 1006.21 -5077.78 5533.00 5456.73 502.61 -72.87 95.75 5686.76 55.64 5631.12 PASS 9900.00} 8197.66 1014.68 -512395 5533.00 5456.73 502.61 -72.87 95.79 5769.60 55.64 5713.96 PASS 10000.00} 8285.96 1023.16 -5170.11 5533.00 5456.73 502.61 -72.87 95.83 5852.98 55.65 5797.33 PASS 10100.00} 8374.26 1031.63 -5216.27 5533.00 5456.73 502.61 -72.87 95.87 5936.87 55.67 5881.20 PASS 10200.001- 8462.56 1040.10 -5262.43 5533.00 5456.73 502.61 -72.87 95.91 602125 55.71 5965.54 PASS 10300.001- 8550.87 1048.57 -530859 5533.00 5456.73 502.61 -72.87 9595 6106.11 55.75 6050.35 PASS 10400.00} 8639.17 1057.05, -5354.75 5533.00 5456.73 502.61 -72.87 95.99 6191.41 55.81 6135.60 PASS 10500.001- 8727.47 1065.52 -540091 5533.00 5456.73 502.61 -72.87 96.03 6277.15 55.88 6221.28 PASS 10600.00} 8815.78 1073.99 -5447.07 5533.00 5456.73 502.61 -72.87 96.07 636331 55.96 6307.35 PASS 10700.00} 8904.08 1082.46 -5493.23 5533.00 5456.73 502.61 -72.87 96.11 6449.87 56.05 6393.82 PASS 1 10800.001- 8992.38 1090.93 -553939 5533.00 5456.73 502.61 -72.87 96.14 6536.81 56.15 6480.66 PASS I 10900.00} 9080.69 1099.41 -558555 5533.00 5456.73 502.61 -72.87 96.18 6624.12 56.26 6567.85 PASS" 11000.00} 9168.99 1107.88 -5631.71 5533.00 5456.73 502.61 -72.87 9621 6711.78 5639 6655.39 PASS. 11100.00} 9257.29 1116.35 -5677.87 5533.00 5456.73 502.61 -72.87 9625 6799.78 56.52 6743.26 PASS €1 24 • • ceB Clearance Report ERE Cook Inlet EnergyOlson 2 VerBAKER - Closest Approach Page 13 of 25 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot Olson 2 Slot _Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek CLEARANCE DATA-Offset Weubore:Olson 1 PB1 Offset Wellpath:Olson 1 PB1 Facility:Olsm Creek Slot:Okm 1 Slot Welt Olson 1 PB1 Threshold Value=0.00 it t=interpolated/extrapolated station Ref MD Ref TVD Ref North Ref East Offset MID Offset TVD Offset North Offset East Horn C-C ACR Ellipse ACR [ft] [ft] [R] [ft] [rt] lit] [it] pt] Bearing Clear Dist MASD Sep Status P] pi [It] [n] 11200.00} 9345.59 1124.82 -5724.03 5533.00 5456.73 502.61' -72.87 96.28 6888.11` 56.67 6831.45 PASS 11300.00} 9433.90 1133.29 -5770.20 5533.00 5456.73 502.61 -72.87 9632 6976.76 56.83 6919.93 PASS 11400.00} 9522.20 1141.77 -5816.36 5533.00 5456.73 502.61 -72.87 9635 7065.71 56.99 7008.72 PASS 11500.00} 9610.50 1150.24 -5862.52 5533.00 5456.73 502.61 -72.87 9638 7154.95 57.17 7097.78 PASS 11600.00} 9698.81 1158.71 -5908.68 5533.00 5456.73 502.61 -72.87 96.42 7244.47 5736 7187.11 PASS 11700.00} 9787.11 1167.18 -5954.84 5533.00 5456.73 502.61 -72.87 96.45 7334.26 5756 7276.71 PASS 11800.00} 9875.41 1175.65 -6001.00i 5533.00 5456.73 502.61 -72.87 96.48 7424.32.. 57.77. 7366.55 PASS 11900.00} 9963.72 1184.13 -6047.16 5533.00 5456.73 502.61 -72.87 9651 7514.62 57.98 7456.64 PASS 11967.90 10023.67 1189.88 -6078.50 5533.00 5456.73 502.61 -72.87 96.53 7576.08 58.14 7517.94 PASS POSITIONAL UNCERTAINTY- Offset Wellbore:Olson 1 PB1 Offset Wellpath:Olson 1 PB1 - Slot Surface Uncertainty @1SD Horizontal 2.0008 Vertical 1.000ft Facility Surface Uncertainty @1 SD Horizontal 20.000ft Vertical 3.000ft HOLE&CASING SECTIONS-Offset Wellbore:Olson 1 PB1 Offset Wellpath:Olson 1 PB1 IString/Dlameter Start MD End MD Interval Start TVD End TVD Start N/S Start E/W End N/S End E/W PI [ft] [it] [It] PI Ertl lff1 [n] [n] 10.75in Conductor 15.30 157.00 141.70 48.10 189.78 -3.35 18.89 j -2.70 18.901 7.625in Casing 15.30 1998.00 1982.70, 48.10 1991.07 -3.35 18.89` 95.87 16.36 6.75in Open Hole 15.30 5715.00[ 5699.70r 48.101 NA -3.35 18.89 NA NAj €3 25 • all Clearance Report Frail Olson 2 Ver#4 Cook Inlet Energy— Closest Approach BAKER Page 14 of 25 III ES REFERENCE WELLPATH IDENTIFICATION .. ,...--] Operator Cook Inlet Energy Slot Olson 2 Slat _Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek WELLPATH COMPOSITION-Offset Wellbore:Olson 1 PBI Offset Weilpath:Olson 1 PB1 Start MD End MD Positional Uncertainty Model LogName/Comment Wellbore [ft] [ft] 1530 1850.00 Genetic gyro-continuous(Standard) Olson 1 PB1 Gyro<0-1850> _ Olson 1 PB1 1850.00 5533.00 ISCWSA MWD,Rev.2,axial magnetic correction(Standard) Olson 1 PB1 MWD<2037-5533> Olson 1 PB1 OFFSET WELLPATH MD REFERENCE- Offset Wetmore:Olson 1 PB! Offset Wellpath:Olson 1 PB1 MD Reference:Rig on Olson 1(RKB) Offiet TVD&local coordinates use Reference Wellpath settings (See WELLPATH DATUM onpage 1 of this report) Ellipse Start MD 339.700 €1 26 caa Clearance Report IfAiill Cook Inlet EnergyOlson 2 rBAKER Closest Approach Page 15 of 25 HUI2trilES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WdlPlm Facility Olson Creek CLEARANCE DATA-Offset Wellbore:Otter#1A Offset Welipath:NavITrak MWD<4436-7021'> Facility:Otter Slot:Otter#1 Welt Otter#1 Threshold Valoe=.00 ft t=Interpolatedlextrapolated station Ref MD Ref TVD Ref North Ref East Off set MD Offset TVD Offset North Off set East Horn C-C ACR Ellipse ACR [ft] lilt] [ft] [ft] [ft] [ft] [it] [ft] Bearing Clear Dist MASD Sep Status _ _ [9 [ft] [ft] [n] 0.00 0.00 0.00 0.00 0.00 149.15 26741.81 27608.57 45.91 38436.70 1.11 3843538 PASS 100.001- 100.00 0.00 0.00 0.00 149.15 26741.81 27608.57 45.91 38436.44 1.11 3843532 PASS 160.001- 160.00 0.00 0.00 10.00 159.15 26741.81 27608.56 45.91 38436.41 1.11 3843529 PASS 200.001- 200.00 0.00 0.00 31.90 181.05 26741.85 27608.54 45.91 38436.42 1.11 3843530 PASS 300.00} 300.00 0.00 0.00 94.63 243.78 26742.14 27608.34 45.91 38436.52 0.80 38435.71 PASS 400.001- 400.00 0.00 0.00 157.35 306.49 26742.74 27607.93 45.91 38436.71 61.10 38375.61 PASS 500.00 500.00 0.00 0.00 229.59 378.73 26743.77 27607.23 45.91 38437.00 61.10 3837590;PASS 600.00} 599.93 0.76 -3.12 322.09 471.20 26745.45 27606.02 45.91 38439.03 61.11 3837792r PASS 684.431- 684.00 239 -10.59 400.00 549.08 26747.14 27604.75 45.92 38443.42 121.44 38321.98 PASS 700.001- 699.45 3.04 -12.45 412.14 561.22 26747.43 27604.53 45.92 38444.50 121.44 38323.05 PASS 800.00} 798.15 6.83 -27.97 489.79 638.83 26749.33 27603.11 45.94 38453.39 121.48 38331.91 PASS 900.001- 895.62 12.11 -49.60 566.62 715.62 26751.36 27601.62 45.96 38465.70 121.53 38344.16 PASS 1000.001- 991.46 18.86 -7727 660.65 80939 26753.98 27599.71 45.99 38481.36 121.61 38359.75 PASS 1100.00} 1085.28 27.06 -110.85 767.06 915.94 26756.99 27597.49 46.03 38500.25 121.71 3837854 PASS 1200.001- 1176.69 3667 -15020 877.67 1026.48 26760.12 27595.11 46.08 38522.30 121.85 38400A5 PASS 1300.001. 1265.31 47.65 -195.17 988.18 1136.92 26763.21 27592.68 46.13 38547.41 122.05 3842536 PASS 1400.00} 1350.78 59.95 -24556 1102.42 1251.08 26766.37 27590.12 46.19 38575.49 122.32 38453.17 PASS 1500.001- 1432.75 73.53 -301.18 1208.10 1356.69 26769.26 27587.68 46.25 38606.43 122.68 38483.75 PASS 1600.001- 1510.88 88.33 -361.79 1273.01 142157 26771.00 27586.21 46.33 38640.18 123.16 38517.02 PASS 1700.001- 1584.84 104.29 -427.15 1334.54 1483.06 26772.61 27584.88 46.41 38676.66 123.79 38552.87 PASS 1800.001- 1654.34 12133 -496.97 1392.421 1540.91 26774.10 27583.69 46.49 38715.71 124.61 38591.11 PASS 1888.30 1711.77 13724 -562.12 1480.57 1629.02 26776.28 27581.94 46.57 38752.20 125.54 38626.66 PASS 1900.001- 1719.12 139.40 -570.96 1492.84 1641.28 26776.57 27581.69 46.58 38757.16 125.68 38631.48 PASS 2000.001- 1781.99 157.84 -64651 1597.66 1746.05 26778.99 27579.62 46.68 38799.50 126.96 3867255 PASS 2013.00 1790.16 16024 -65633 1607.62 1756.01 26779.21 27579.42 46.69 38805.01 127.03 38677.99 PASS 2100.001- 1846.57 175.66 -720.74 1671.07 1819.43 26780.63 27578.16 46.77 38841.38 128.11 3871327 PASS 2200.00} 1915.50 191.80 -79134 1748.47 1896.79 26782.39 27576.57 46.85 38881.85 129.47 3875239 PASS 2300.00} 1988.58 206.19 -858.05 1831.761 1980.04 26784.32 27574.811 46.93 38920.74 130.76 38789.98 PASS 2400.00-f- 2065.55 218.77 -92061, 1921.83 2070.06 26786.45 27572.82 47.00 38957.89 131.99 38825.90 PASS 1 2410.70 2074.00 220.01 -927.05 1931.72 2079.95 26786.68 27572.60 47.01 38961.75 132.11 38829.64 PASS €3 27 • • tett Clearance Report FAIIIII Olson 2r BAKER Cook Inlet Energy Closest Approach Page 16 of 25 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WeliPlan� Facility Olson Creek CLEARANCE DATA-Offset Weubore:Otter#1A Offset Wellpsth:NavlTrak MWD<4436-7021'> Facility:Otter Slot Otter#1 Welt Otter#1 Threshold Vakse=.00 ft t=Interpolated/extrapolated statim Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Herb C-C ACR Ellipse ACR [ry rt] [ft] [n] try [rt] rill [ft] Bearing Clear Dist MASD Sep Status [1 [R] fit] fit] 2420.90 1 2082.06 221.19 -933.19 1941.15 2089.37 26786.91 27572.39 47.02 38965.44 132.23 38833.21 PASS 2500.001- 2144.45 23032 -980.95 2006.99 2155.17 26788.51 27570.88 47.07 38994.15 133.17 38860.98 PASS 2600.00f 2223.33 241.87 -1041.32 2052.58 2200.73 26789.69 27569.78 47.14 39030.53 134.39 38896.14 PASS 2700.00f 2302.21 253.42 -1101.70 2098.27 2246.40 26791.00 27568.63 47.21 39067.04 135.65 38931.39 PASS 2800.00f 2381.08 26497 -1162.07 2144.07 2292.16 26792.44 27567.42 47.28 39103.68 136.96 38966.73 PASS 2900.00f 2459.96 27652 -1222.45 2189.98 2338.02 26793.99 27566.15 47.35 39140.45 138.30 39002.15 PASS 3000.00 f 2538.83 288.07 -1282.82 2234.04 2382.04; 26795.60 27564.89 47.42 39177.34 139.67 39037.67 PASS 3100.00f 2617.71 299.62 -134320 2277.64 2425.59' 26797.29 27563.60 47.49 39214.36 141.08 39073.28 PASS 3200.001. 2696.59 311.17 -140357 2321.32 2469.20 26799.08 27562.27 47.56 39251.51 142.53 39108.99 PASS 3300.001. 2775.46 322.72 -1463.95 2365.06 2512.89 2680099 27560.90 47.63 39288.79 144.00 39144.80 PASS 3400.00 f 2854.34 33427 -152432 2423.12 2570.86 26803.66 27559.03 47.69 39326.20 145.51 39180.70 PASS 3500.00f 2933.22 345.82 -1584.70 2512.73 2660.30 26808.04 27555.88 47.76 39363.64 147.06 39216.58 PASS 3600.00 f 3012.09 35737 -1645.07 2551.50 2699.00 26810.02 27554.48 47.83 39401.19 148.61 39252.58 PASS 3700.001- 3090.97 368.92 -1705.45 2590.27 2737.69 26812.05 27553.08 47.89 39438.88 150.18 39288.69 PASS 3800.001. 3169.84 380.47 -1765.82 2614.20 2761.56 2681334 27552.21 47.96 39476.71 151.77 39324.94 PASS 3900.001. 3248.72 392.02 -182620 2633.16 2780.48 26814.41 27551.54 48.03 39514.72 153.37 39361.35 PASS 4000.001. 3327.60 40357 -188657 2652.11 2799.39 2681551 27350.86 48.10 39552.90 154.99 39397.92 PASS 4100.001- 3406.47 415.12 -194695 2671.07 2818.30 26816.66 27550.19 48.17 39591.27 156.62 39434.65 PASS 4200.001. 3485.35 426.67 -200732 2690.03 2837.21 26817.85 27549.53 48.24 39629.81 158.27 39471.54 PASS i 4300.00t 3564.23 438.22 -2067.70 2705.48 2852.62 26818.85 27548.99 48.31 39668.52 159.94 39508.59 PASS 4400.00t 3643.10 449.77 -2128.07 2717.03 2864.14 26819.62 27548.59 48.38 39707.43 161.61 39545.82 PASS 1 t 4500.00f 3721.98 46132 -2188.45 2728.58 2875.65-- 26820.41 27548.20 48.45 39746.53 163.30 39583.23 PASS I f 4600.00t 3800.85 472.87 -2248.82 2740.12 2887.16 26821.23 27547.82 48.52 39785.81 165.00 39620.81 PASS 4700.00 f 3879.73 484.42 -230920 2751.66 2898.66 26822.08 27547.44 48.58 39825.28 166.71 39658.58 PASS 4800.001. 3958.61 495.97 -236937 2763.19 2910.15 26822.94 27547.07 48.65 39864.94 168.43 39696.52 PASS 4900.001. 4037.48 50732 -242995 2774.72 2921.64 26823.83 27546.70 48.72 39904.79 170.16 39734.64 PASS 5000.00t 4116.36 519.07 -249032 2786.24 2933.12 26824.74 27546.34 48.79 39944.83 171.89 39772.93 PASS 5100.001, 4195.24 530.62 -2550.70 2797.76 2944.59 26825.68 27545.98 48.86 39985.05 173.64 39811.41 PASS 5200.00t 4274.11 542.17 -2611.07 2811.91 2958.69 26826.86 27545.55 48.92 40025.46 175.40 39850.06-1 PASS 5300.00t 4352.99 553.72 -2671.45 2826.69 2973.41 26828.12 27545.11 48.99 40066.04 177.16 39888.88 PASS €1 28 • • caa Clearance Report ll'ARIII Olson 2`er#4 pros BAKER Cook Inlet Energy Closest Approach Page 17 of 25 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek CLEARANCE DATA-Offset Wellbore:Otter#1A Offset Wellpatlt:NavlTrak MWD<4436-7021'> € Facility:Otter Slot Otter#1 Welt Otter#1 Threshold Vakie=0A0 ft t=interpolated/extrapolated statim Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Hora C-C ACR Ellipse ACR I [ft] pt] [rt] [111 itt] [ft] gt] [R] Bearing Clear Dist MASD Sep Status 11 [ft] 8t] ] 5400.00} 4431.86 56527 -2731.82 2841.47 2988.13 26829.42 27544.68 49.06 40106.81 178.93 39927.87 PASS 5500.00} 4510.74 576.82 -279220 2856.24 3002.84 26830.74 27544.25 49.13 40147.75 180.71 35967.041,PASS 5600.001- 4589.62 58837 -285237 2871.01 3017.54 26832.09 27543.82 49.19 40188.87 182.49 4000637 PASS 5700.00} 4668.49 59992 -2912.95 2885.77 3032.22 26833.47 27543.41 49.26 40230.16 184.28 40045.88 PASS 5800.001- 4747.37 611.47 -2973.32 2900.52 3046.90 26834.88 27543.00 49.33 40271.63 186.07 40085.56 PASS 5900.00} 4826.25 623.02 -3033.70 2915.17 3061.48 2683631 27542.60 49.39 40313.28 187.87 40125.41 PASS 6000.00} 4905.12 63437 -3094.07 2929.81 3076.04 26837.76 27542214 49A6; 40355.10 189.67 40165.43 PASS 6100.00} 4984.00 646.12 -3154A5 2944.44 3090.59 26839.23 27541.84 49.53' 40397.10 191.47 40205.63 PASS 6200.00} 5062.87 657.67 -3214.82 2959.05 3105.11 26840.72 27541.48 49.59 40439.27 193.28 40245.99 PASS 6300.00} 5141.75 66922 -327520 2973.64 3119.62 2684224 27541.13 49.66 40481.62 195.09 40286.53 PASS 6400.00} 5220.63 680.77 -333537 2988.22 3134.12 26843.78 27540.79 49.72 40524.14 196.90 40327.24 PASS 6500.00} 5299.50 69232 -3395.95 3003.16 3148.97 2684538 27540.45 49.79 40566.83 198.71 40368.12 PASS 6600.00} 5378.38 703.87 -345632 3019.72 3165.43 26 847.1 8 27540.09 49.86 40609.69 200.53 40409.16 PASS III, 6700.00} 5457.25 715.42 -3516.70 3036.27 3181.87 26849.01 27539.73 49.92 40652.72 202.35 40450.37 PASS 6800.001- 5536.13 72697 -3577.07 3052.80 3198.29 26850.87 27539.39 49.99 40695.92 204.17 40491.75 PASS 6900.00} 5615.01 73852 -3637.44 3069.32 3214.70 26852.77 27539.05 50.05 40739.28 206.00 40533.29 PASS 7000.001- 5693.88 750.07 -3697.82 3085.83 3231.10 26854.68 27538.72 50.11 40782.81 207.82 40574.99 PASS 7100.00} 5772.76 761.62 -3758.19 3101.91 3247.06 2685658 27538.41 50.18 40826.51 209.64 40616.87 PASS 7200.00} 5851.64 773.17 -381837 3115.41 3260.46 26858.20 27538.16 50.24 40870.37 211.46 40658.91 PASS 7300.00} 5930.51 784.72 -387894 3128.90 3273.85 26859.84 27537.91 50.31 40914.41 213.28 40701.12 PASS 7400.00} 6009.39 79627 -393932 3142.38 3287.22 2686150; 27537.68 50.37 40958.61 215.10f 40743.51 PASS 7446.50 6046.07 801.64 -396739 3148.64 3293.43 2686228 27537.58 50.40 40979.23 215.951 40763.28 PASS 7500.001- 6088.72 807.69 -3999.11 3155.91 3300.64 26863.19 27537.46 50.44 41002.65 216.90 40785.76 PASS 7600.00} 6170.80 81831 -405522 3169.85 3314.47 26864.95 27537.24 50.50 41044.72 218.44 40826.28 PASS 7700.00} 6255.76 828.01 -4107.05 3184.22 3328.73 26866.79 27537.02 50.55 41084.47 219.90 40864.57 PASS 7777.90 6323.78 83490 -414437 3195.69 3340.10 26868.28 27536.86 50.59 41113.74 220.91 40892.83 PASS 7800.00} 6343.29 836.77 -415437 3198.98 3343.35 26868.71 27536.82 50.60 41121.84 221.18 40900.65 PASS 7900.00} 6431.60 84524 -4200.73 3212.94 3357.19 2687035 27536.63 50.65 41158.58 222.421 40936.171_PASS 8000.00} 6519.90 853.72 -4246.89 3226.82 3370.95 26872.41 27536.46 50.70 41195.50 223.65 40971.86 PASS 8100.00} 6608.20 862.19 -4293.05 3240.69 3384.69 2687429 27536.30 50.74 41232.61 224.88 41007.73 PASS €8 29 • • cell Clearance Report Olson 2 Ver#4 BAKER _ Cook Inlet Energy Closest Approach Page 18 of 25 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WeilPlan Facility Olson Creek CLEARANCE DATA-Offset Wellbore:Otter#1A Offset Wellpath:NavITrak MVVD<4436-7021'> Facility:Otter Slot Otter#1 Welk Otter#1 Threshold V8We=0A0 ft t=interpolated/extrapolated statim Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Hora C-C ACR Ellipse ACR [R] [R] [R] [ft] [ft] 8t] [It] [it] Bearing Clear Dist MASD Sep Status [9 [n] pt] Ft] 8200.00} 6696.51 870.66 -4339.21 3254.54 3398.41 26876.19 27536.15 50.79 41269.89 226.11 41043.78 PASS 8300.00} 6784.81 879.13 -4385.37 3268.38 3412.11 26878.12 2753691 50.84 41307.35 22734 41080.01 PASS 8400.00} 6873.11 887.60 -4431.53 3282.20 3425.79 26880.07 27535.89 50.89 41344.99 22857 41116.42 PASS 8500.00} 6961.41 896.08 -4477.69 3296.01 3439.45 26882.04 27535.77 50.93 41382.80 229.80 41153.01 PASS 8600.00} 7049.72 90435 -4523.86 7006.35 7134.37 2708658 2756591 50.79 41415.69 23427 41181.42 PASS€ 8700.00} 7138.02 913.02 -4570.02 7021.00 7149.02 2708630 27566.10 50.84 41446.00 23553 41210.47 PASS 8800.00} 7226.32 921.49 -4616.18 7021.00 7149.02 2708630 27566.10 50.89 41476.53 236.79 41239.74 PASS 8900.00} 7314.63 929.96 -4662.34 7021.00 7149.02 2708630 27566.10 50.94 41507.27 238.04 4126923 PASS 9000.00} 740293 938.44 -4708.50 7021.00 7149.02 2708630 27566.10 50.99 41538.24 239.29 4129895 PASS 9100.00} 7491.23 946.91 -4754.66 7021.00 7149.02 2708630 27566.10 51.04 41569.42 24054 41328.88 PASS 9200.00} 7579.54 95538 -4800.82 7021.00 7149.02 2708630 27566.10 51.09 41600.82 241.79 41359.03 PASS 9300.00} 7667.84 963.85 -4846.98 7021.00 7149.02 2708630 27566.10 51.13 41632.43 243.04 4138939 PASS 9400.00} 7756.14 97232 -4893.14 7021.00 7149.02 2708630 27566.10 51.18 41664.26 24428 41419.98 PASS 9500.00} 7844.44 980.80 -4939.30 7021.00 7149.02 2708630 27566.10 51.23 41696.31 24553 41450.78 PASS 9600.00} 7932.75 989.27 -4985.46 7021.00 7149.02 2708630 27566.10 51.28 41728.57 246.77 41481.80 PASS 9700.00} 8021.05 997.74 -5031.62 7021.00 7149.02 2708630 27566.10 51.33 41761.05 248.01 41513.04 PASS 9800.00} 8109.35 1006.21 -5077.78 7021.00 7149.02 2708630 27566.10 51.38 41793.74 24925 41544.49 PASS 9900.00} 8197.66 1014.68 -5123.95 7021.00 7149.02 2708630 27566.10 51.43 41826.64 250.49 41576.15 PASS 10000.00} 8285.96 1023.16 -5170.11 7021.00 7149.02 2708630 27566.10 51.48 41859.76 251.73 41608.03 PASS 10100.00} 8374.26 1031.63 -5216.27 7021.00 7149.02 2708630 27566.10 51.52 41893.09 252.96 41640.13 PASS 10200.00} 8462.56 1040.10 -5262.43 7021.00 7149.02 2708630 27566.10 51.57 41926.63 254.19 41672.44 PASS 10300.00} 8550.87 104857 -5308.59 7021.00 7149.02 2708630 27566.10 51.62 41960.38 255.43 41704.96 PASS 10400.00} 8639.17 1057.05 -5354.75 7021.00 7149.02 2708630 27566.10 51.67 41994.35 256.66 41737.69 PASS 10500.00} 8727.47 106552 -5400.91 7021.00 7149.02 2708630 27566.10 51.72 42028.52 257.88 41770.64 PASS 10600.00} 8815.78 1073.99 -5447.07 7021.00 7149.02 2708630 27566.10 51.76 42062.91 259.11 41803.80 PASS 10700.00} 8904.08 1082.46 -5493.23 7021.00 7149.02 2708630 27566.10 51.81 42097.50 26033 41837.17 PASS 10800.00} 8992.38 1090.93 -5539.39 7021.00 7149.02 2708630 27566.10 51.81 42132.30 26155 41870.75 PASS 10900.001. 9080.69 1099.41 -5585.551 7021.00 7149.02 2708630 27566.10 51.91 42167.31 262.77 4190454 PASS 11000.001. 9168.99 1107.88 -5631.71 7021.00 7149.02 2708630 27566.10 51.96 42202.53 263.99 41938.54 PASS 11100.00} 9257.29 111635 -5677.87 7021.00 7149.02 2708630 27566.10 52.00 42237.96 26521 41972.75 PASS €6 30 • S Clearance Report ii Cook Inlet Energy Closest Apper#4 roach BAKER Page 19 of 25 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot Olson 2 Slat Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek CLEARANCE DATA-Offset Wellbore:Otter#1A Offset Wellpath:Nav4Tratc MWD<4436-7021'> Facility:Otter Slot Otter#1 Welt Otter#1 Threshold Value=0.00 ft 1=interpolatedlextrapolated station Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Horiz C-C ACR Ellipse ACR Rt] [ft] [h] [It] [ft] pt] [ft] [ft] Bearing Clear Dist MASD Sep Status P] lftl [it] [ft] 11200.00} 9345.59 1124.82 -5724.03 7021.00 7149.02 2708630 27566.10 52.05 4227339 266.42 42007.17 PASS 11300.00} 9433.90 1133.29 -5770.20 7021.00 7149.02 2708630 27566.10 52.10 42309.43 267.63 42041.80 PASS 11400.00} 9522.20 1141.77 -581636 7021.00 7149.02 2708630 27566.10 52.15 42345.48 268.84 42076.64 PASS 11500.00} 9610.50 1150.24 -5862.52 7021.00 7149.02 2708630 27566.10 52.19 42381.73 270.05 42111.68 PASS 11600.00} 9698.81 1158.71 -5908.68 7021.00 7149.02 2708630 27566.10 52.24 42418.18 27125 42146.93 PASS 11700.00} 9787.11 1167.18 -5954.84 7021.00 7149.02 2708630 27566.10 52.29 42454.84 272.46 42182.39 PASS 11800.00} 9875.41 1175.65 -6001.00 7021.00 7149.02, 2708630 27566.10 52.34 42491.71 273.661 42218.05 PASS 11900.00} 9963.72 1184.13 -6047.16 7021.00 7149.02 2708630 27566.10 52.38 42528.77 274.86 42253.92 PASS 11967.90 10023.67 1189.88 -6078.50 7021.00 7149.02 2708630 27566.10 52.41 42554.06 275.67 42278.39 PASS POSITIONAL UNCERTAINTY- Offset Wellbore:Otter#1A Offset Wellpath:Nav1TrakMWD<4436-7021'> Slot Surface Uncertainty @1SD Horizontal 2.000ft Vertical 1.0008 ---- ,Facility Surface Uncertainty @1SD Horizontal 20.000ft Vertical 3.00011 WELLPATH COMPOSITION-Offset Wellbore:Otter#lA Offset Wcllpath:NaviTraicMWD<4436-7021'> Start MD End MD Positional Uncertainty Model Log Name/Comment Wen ore [ft] [ft] Y 0.00 4400.00 Genetic gyro-continuous(Drillpipe) Otter#1 OMS(200-5686) Otter#1 4400.00 7021.00 Navilfak(Standard) NaviTrak MWD<4436-7021'> Otter#1A OFFSET WELLPATH MD REFERENCE- Offset Wellbore Otter#1A Offset Wellpath:NaviTrak MWD<4436-7021'> [MD Reference:Miller Rig#34(RTE) Offset TVD&local coordinates use Refirence Wellpath settings (See WELLPATH DATUM on page 1 of this report) Ellipse Start MD 324.4011 EA 31 S • cell Clearance Report VAIN Cook Inlet EnergyOlson 2 rBAKER - Closest Approach Page 20 of 25 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellb ore Olson 2 WellPlan Facility Olson Creek , CLEARANCE DATA-Offset Wellbore:Otter#1 Offset Wellpath:Otter#1<0-5686> Facility:Otter Slot Otter#1 Welk Otter#1 Threshold Vahte"O.00 ft t=interpolatedlextrapolated station Ref MI) Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Hor¢ C-C ACR Ellipse ACR Ertl 8t] lR] Ertl [ft] [ft] [ft] [ft] Bearing Clear Dist MASD Sep Status PI [ft] [ft] [n] 0.00 0.00 0.00 0.00 0.00 149.15 26741.81 27608.57 45.91 38436.70 1.01 38435.69 PASS 100.001' 100.00 0.00 0.00 0.00 149.15 26741.81 27608.57 45.91 38436.44 1.01 38435A3 PASS 160.001' 160.00 0.00 0.00 10.00 159.15 26741.81 27608.56 45.91 38436.41 1.01 38435.40 PASS 200.001' 200.00 0.00 0.00 31.90 181.05 26741.85 27608.54 45.91 38436.42 1.01 38435.41 PASS 300.001' 300.00 0.00 0.00 94.63 243.78 26742.14 27608.34 45.91 38436.52 0.85 38435.67 PASS 400.00} 400.00 0.00 0.00 157.35 306.49 26742.74 27607.93 45.91 38436.71 60.99 38375.72 PASS 500.00 500.00 0.00 0.00 229.59 378.73 26743.77 27607.23 45.91 38437.00 60.99 38376.01 PASS 600.001- 599.93 0.76 -3.12 322.09 471.20 26745.45 27606.02 45.91 38439.03 61.00 38378.03 PASS 684.431' 684.00 259 -10.59 400.00 549.08 26747.14 27604.75 45.92 38443.42 121.33 38322.09 PASS 700.001' 699.45 3.04 -12.45 412.14 561.22 26747.43 27604.53 45.92 38444.50 121.33 38323.16 PASS 800.001' 798.15 6.83 -27.97 489.79 638.83 26749.33 27603.11 45.94 38453.39 121.37 38332.02 PASS I 900.001' 895.62 12.11 -49.60 566.62 715.62 26751.36 27601.62 45.96 38465.70 121.42 38344.27 PASS 1000.001' 991.46 18.86 -77.27 660.65 80939 26753.98 27599.71 45.99 38481.36 121.50 38359.86 PASS 1100.001. 1085.28 27.06 -110.85 767.06 915.94 26756.99 27597.49 46.03 38500.25 121.60 38378.65 PASS 1200.001' 1176.69 36.67 -15020 877.67 1026.48 26760.12 27595.11 46.08 38522.30 121.74 3840036 PASS 1300.001' 1265.31 47.65 -195.17 988.18 113692 26763.21 27592.68 46.13 38547.41 121.94 38425.47 PASS 1400.001' 1350.78 59.95 -245.56 1102.42 1251.08 26766.37 27590.12 46.19 38575.49 122.21 3845328 PASS 1500.001' 1432.75 7333 -301.18 1208.10 1356.69 2676_9.26 27587.68 46.25 38606.43 122.57 38483.86 PASS 1600.001' 1510.88 8833 -361.79 1273.01 142137 26771.00 27586.21 46.33 38640.18 123.05 38517.13 PASS 1700.001' 1584.84 10429 -427.15 1334.54 1483.06 26772.61 27584.88 46.41 38676.66 123.68 38552.98 PASS 1800.001. 1654.34 12133 -496.97 1392.42 1540.91 26774.10 27583.69 46.49 38715.7k 124.50 38591.22 PASS 1888.30 1711.77 137241 -562.12 1480.57 1629.02 26776.28 27581.94 46.57 38752.20 125.43 38626.77 PASS 1900.001- 1719.12 139.40 -570.96 1492.84 164128 26776.57 27581.69 46.58 38757.16 125.57 3863138 PASS 2000.001- 1781.99 157.84 -64631 1597.66 1746.05 26778.99 27579.62 46.68 38799.50 126.85 38672.65 PASS 2013.00 1790.16 16024 -65633 1607.62 1756.01 26779.21 27579.42 46.69 38805.01 126.92 38678.09 PASS 2100.001. 1846.57 175.66 -720.74 1671.07 1819.43 26780.63 27578.16 46.77 38841.38 128.11 3871327 PASS 2200.001' 1915.50 191.80 -79134 1748.47 I896.79 26782.39 27576.57 46.85 38881.85 129.47 3875239 PASS 2300.001- 1988.58 206.19 -858.05 1831.76 1980.04 26784.32 27574.81 46.93 38920.74 130.76 38789.98 PASS 2400.00} 2065.55 218.77 -920.61 1921.83 2070.06 26786.45 27572.82 47.00 38957.89 131.99 38825.90 PASS 2410.70 2074.00 220.01 -927.05 1931.72 207995 26786.68 27572.60 47.01 38961.75 132.11 38829.64 PASS €8 32 1 0 0 oeB Clearance Report iI Cook Inlet EnergyOlson 2 VerBAKER - Closest Approach Page 21 of 25 HES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek CLEARANCE DATA-Offset Weabore:Otter#1 Offset Wdlpath:Otter#1<0-5686> I Facility:Otter Slot:Otter#1 Welt Otter#1 Threshold Value=0.00 ft 1,=interpolated/extrapolated statim Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Hark C-C ACR Ellipse ACR [ft] [ft] [ft] [R] p't] pi Ft] [rt] Bearing Clear Dist MASD Sep Status P] [R] tut] [ft] 2420.90 2082.06 221.19 -933.19 1941.15 2089.37 26786.9f 27572.39 47.02 38965.44 132.23 38833.21 PASS 2500.00} 2144.45 23032 -980.95 2006.99 2155.17 26788.51 27570.88 47.07 38994.15 133.17 38860.98 PASS 2600.00} 2223.33 241.87 -104132 2052.58 2200.73 26789.69 27569.78 47.14 39030.53 134.39 38896.14 PASS 2700.00} 2302.21 253.42 -1101.70 2098.27 2246.40 26791.00 27568.63 47.21 39067.04 135.55 38931.49 PASS 2800.00} 2381.08 264.97 -1162.07 2144.07 2292.16 26792.44 27567.42 47.28 39103.68 136.85 38966.83 PASS 2900.00} 2459.96 27632 -1222.45 2189.98 2338.02 26793.99 27566.15 47.35 39140.45 138.19 39002.25 PASS 3000.00}; 2538.83, 288.07 -1282.82 2234.04 2382.04 26795.60 27564.89 47.42 39177.34 139.57 39037.77 PASS 3100.00# 2617.71 299.62 -134320 2277.64 2425.59 26797.29 27563.60 47.49 39214.36 140.98 39073.38 PASS 3200.00} 2696.59 311.17 -140357 2321.32 2469.20 26799.08 27562.27 47.56 39251.51 142.42 39109.09 PASS 3300.00} 2775.46 322.72 -146395 2365.06 2512.89 26800.99 27560.90 47.63 39288.79 143.89 39144.90 PASS 3400.001. 2854.34 334.27 -1524.32 2423.12 2570.86 26803.66 27559.03 47.69 39326.20 145.40 39180.80 PASS I 3500.00} 2933.22 345.82 -1584.70 2512.73 2660.30 26808.04 27555.88 47.76 39363.64 146.96 39216.69 PASS I 3600.00} 3012.09 35737 -1645.07 2551.50 2699.00 26810.02 27554.48 47.83 39401.19 148.51 39252.68 PASS 3700.00} 3090.97 368.92 -1705.45 2590.27 2737.69 26812.05 27553.08 47.89 39438.88 150.08 39288.80 PASS 3800.00} 3169.84 380.47 -1765.82 2614.20 2761.56 2681334 27552.21 47.96 39476.71 151.66 39325.05 PASS' 3900.00} 3248.72 392.02 -182620 2633.16 2780.48 26814.41 27551.54 48.03 39514.72 153.26 39361.46 PASS 4000.00} 3327.60 403.57 -188637 2652.11 2799.39 2681551 27550.86 48.10 39552.90 154.88 39398.02 PASS 4100.00} 3406.47 415.12 -1946.95 2671.07 2818.30 2681666 27550.19 48.17 39591.27 156.52 39434.75 PASS 4200.00} 3485.35 426.67 -2007.32 2690.03 2837.21 26817.85 27549.53 48.24 39629.81 158.17 39471.64 PASS 4300.00} 3564.23 438.22 -2067.70 2705.48 2852.62 26818.85 27548.99 48.31 39668.52 159.83 39508.69 PASS" 4400.00} 3643.10 449.77 -2128.07 2717.03 2864.14 26819.62 27548.59 48.38 39707.43 161.51 39545.92 PASS 4500.00} 3721.98 46132 -2188.45 2728.58 2875.65 26820.41 27548.20 48.45 39746.53 163.19 39583.33 PASS 4600.001. 3800.85 472.87 -2248.82 2740.12 2887.16 2682123 27547.82 48.52 39785.81 164.89 39620.921 PASS 4700.00} 3879.73 484.42 -230920 2751.66 2898.66 26822.08 27547.44 48.58 39825.28 166.60 39658.68 PASS 4800.00} 3958.61 49597 -2369.57 2763.19 2910.15 26822.94 27547.07 48.65 39864.94 168.32 39696.62 PASS 4900.00} 4037.48 50752 -2429.95 2774.72 2921.64 26823.83 27546.70 48.72 39904.79 170.05' 39734.74 PASS 5000.00} 4116.36 519.07 -249032 2786.24 2933.12 26824.74 27546.34 48.79 39944.83 171.79 39773.04 PASS 5100.00} 4195.24 530.62 -2550.70 2797.76 2944.59 26825.68 27545.98 48.86 39985.05 173.54_ 39811.51 PASS 5200.00} 4274.11 542.17 -2611.07 2811.91 2958.69 26826.86 27545.55 48.92 40025.46 175.29. 39850.16 PASS 5300.00} 4352.99 553.72 -2671.45 2826.69 2973.41 26828.12 27545.11 48.99 40066.04 177.06 39888.98 PASS €8 33 0 • Clearance Report Ft11111 Olson 2 vera BAKER _ Cook Inlet Energy_ Closest sestApproach Page 22 of 25 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy 'Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek CLEARANCE DATA-Offset WeMbore:Otter#1 Offset Wel[path Otter#1<0-5686> Facility:Otter Slot Otter#1 Welt Otter#1 Threshold Yalu t0.00 ft f=interpolatediestrapolated station f1 Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Onset East Florh C-C ACR Ellipse ACR [ft] [ft] [ft] [ft] irt] Qt] Irt] [Ill Bearing Clear Dist MASD Sep Status [I [ft] [It] Ertl 5400.00} 4431.86 56527 -2731.82f 2841.47 2988.13 26829.42 27544.68 49.06 40106.81 178.83 39927.98 PASS 5500.00} 4510.74 576.82 -2792.20 2856.24 3002.84 26830.74 27544.25 49.13 40_147.75 180.61 39967.14 PASS 5600.00} 4589.62 58837 -285237 2871.01 3017.54 26832.09 27543.82 49.19 40188.87 182.39, 40006.48 PASS 5700.00} 4668.49 599.92 -2912.95 2885.77 3032.22 26833.47 27543.41 49.26 40230.16 184.181 40045.991 PASS 5800.00} 4747.37 611.47 -297332 2900.52 3046.90 26834.88 27543.00 49.33 40271.63 185.97 40085.66 PASS It 5900.00} 4826.25 623.02 -3033.70 2915.17 3061.48 2683631 27542.60 49.39 40313.28 187.77 40125.52 PASS 6000.00} 4905.12 63437 -3094.07 2929.81 3076.04 26837.76 27542.21 49.46 40355.10 189.57 40165.54 PASS 6100.00} 4984.00 646.12 -3154.45 2944.44 3090.59 26839.23 27541.84 49.53 40397.10 191.37 40205.73 PASS 6200.00} 5062.87 657.67 -3214.82 2959.05 3105.11 26840.72 27541.48 49.59 40439.27 193.18 40246.10 PASS 6300.00} 5141.75 66922 -327520 2973.64 3119.62 26842.24 27541.13 49.66 40481.62 194.98 40286.64 PASS, 6400.00} 5220.63 680.77 -333557 2988.22 3134.12 26843.78 27540.79 49.72 40524.14 196.80 40327.34 PASS 6500.001- 5299.50 69232 -3395.95 3003.16 3148.97 2684538 27540.45 49.79 40566.83 198.61 40368.22 PASS 6600.00} 5378.38 703.87 -345632 3019.72 3165.43 26847.18 27540.09 49.86 40609.69 200.43 40409.26 PASS• 6700.00} 5457.25 715.42 -3516.70 3036.27 3181.87 26849.01 27539.73 49.92 40652.72 202.25 40450.47 PASS 6800.001- 5536.13 726.97 -3577.07 3052.80 3198.29 26850.87 2753939 49.99 40695.92 204.07 40491.85 PASS 6900.001. 5615.01 73852 -3637.44 3069.32 3214.70 26852.77 27539.05 50.05 40739.28 205.89 40533.39 PASS 7000.001. 5693.88 750.07 -3697.82 3085.83 3231.10 26854.68 27538.72 50.11 40782.81 207.71 40575.10 PASS 7100.001- 5772.76 761.62 -3758.19 3101.91 3247.06 26856.58 27538.41 50.18 40826.51 209.54 40616.97 PASS 7200.001- 5851.64 773.17 -3818.57 3115.41 3260.46 26858.20 27538.16 50.24 40870.37 211.36 40659.01 PASS 7300.001- 5930.51 784.72 -3878.94 3128.90 3273.85 26859.84 27537.91 50.31 40914.41 213.18 40701.23 PASS 7400.00} 6009.39 79627 -393932 3142.38 3287.22 26861.50 27537.68 50.37 40958.61 215.00 40743.61 PASS 7446.50 6046.07 801.64 -396739 3148.64 3293.43 26862.28 27537.58 50.40 40979.23 215.85 40763.38 PASS 7500.001- 6088.72 807.69 -3999.11 3155.91 3300.64 26863.19 27537.46 50.44 41002.65 216.79 40785.861 PASS 7600.001- 6170.80 81831 -4055.22 3169.85 3314.47 26864.95 27537.24 50.50 41044,72 218.34 40826.39 PASS 7700.001- 6255.76 828.01 -4107.05 3184.22 3328.73 26866.79 27537.02 50.55 41084.47 219.79 40864.67 PASS 7777.90 6323.78 834.90 -414437 3195.69 3340.10 26868.28 27536.86, 50.59 41113.74 220.81 40892.94 PASS 7800.001. 6343.29 836.77 -4154.57 3198.98 3343.35 26868.71 27536.821 50.60 41121.84 221.08 40900.76 PASS 7900.00} 6431.60 845241_-4200' .73 3212.94 3357.19 26870.55 27536.63 50.65 41158.58 222.31 40936.27 PASS 1 8000.00} 6519.90 853.72 -4246.89 3226.82 3370.95 26872.41 27536.46 50.70 41195.50 223.54 40971.96 PASS 8100.001- 6608.20 862.19 -4293.05 3240.69 3384.69 26874.29 27536.30 50.74 41232.61 224.77 41007.83 PASS 34 S • ae6 Clearance Report FA,. Cook Inlet EnerOlson 2 Ver#4 - Energy Closest Approach BAKER Page 23 of 25 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot ;Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well101son 2 Field Olson Creek Unit Wellbore (Olson 2 WeilPlan Facility Olson Creek CLEARANCE DATA-Offset Wellbore:Otter#1 Offset Wdlpath:Otter#1<0-5686> Facility:Otter Slat Otter#1 Welt Otter#1 Threshold Vakie=0.00 ft t=interpolated/extrapolated statim Ref MD Ref TVD Ref North Ref East Offset MD Offset TVD Offset North Offset East Hark C-C ACR Ellipse ACR [ft] [it] [ft] [ft] [ft] [ft] [ft Bearing Clear Dist MASD SepStatus 1 [n] 6 PI [ft] fit] @'t] 8200.00} 6696.51 870.66 -4339.21 3254.54 3398.41 26876.19 27536.15 50.79 41269.89 226.00 41043.88 PASS 8300.00} 6784.81 879.13 -4385.37 3268.38 3412.11 26878.12 27536.01 50.84 41307.35 227.23 41080.11ii PASS 8400.00} 6873.11 887.60 -4431.53 3282.20 3425.79 26880.07 27535.89 50.89 41344.99 228.46 41116.52 PASS 8500.00} 6961.41 896.08 -4477.69 3296.01 3439.45 26882.04 27535.77 50.93 41382.80 229.69 41153.11 PASS 8600.00} 7049.72 90455 -4523.86 3311.36 3454.65 2688426 27535.66 50.98 41420.80 23092 41189.87 PASS 8700.00} 7138.02 913.02 -4570.02 3327.33 3470.44 2688639 2753536 51.03 41458.96 232.15 41226.81 PASS 8800.001 7226.321 921.49 -4616.18 3343.28 3486.22 26888.95 27535.47 51.07 41497.30 23338 41263.92 PASS 8900.004' 7314.63 929.96 -4662.34 3359.20 3501.96 2689132 27535.40 51.12 41535.80 234.61 4130120 PASS 9000.00} 7402.93 938.44 -4708.50 3375.11 3517.69 26893.72 2753535 51.17 41574.48 235.84 41338.65 PASS 9100.00} 7491.23 94691 -4754.66 3390.99 3533.38 26896.13 2753532 51.21 41613.33 237.06 4137627 PASS 9200.00} 7579.54 95538 -4800.82 3407.67 3549.86 26898.69 2753530 51.26 41652.35 238.29 41414.06 PASS 9300.00} 7667.84 963.85 -4846.98 3425.39 3567.38 26901.44 2753529 51.31 41691.54 23932 41452.02 PASS 9400.00} 7756.14 97232 -4893.14 3443.10 3584.86 2690421 2753531 51.35 41730.89 240.74 41490.14 PASS 9500.00} 7844.44 980.80 -4939.30 3460.78 3602.32 26907.01 2753534 51.40 41770.40 241.97 41528.43 PASS 9600.00} 7932.75 98927 -4985.46 3478.43 3619.75 26909.82 2753539 51.44 41810.08 243.19 41566.89 PASS 9700.00} 8021.05 997.74 -5031.62 3496.06 3637.15 26912.66 27535.45 51.49 41849.92 244.42 4160531 PASS I 9800.00} 8109.35 1006.21 -5077.78 3555.38 3695.68 2692228 27535.72 51.53 41889.90 245.72 41644.17 PASS I 9900.00} 8197.66 1014.68 -5123.95 3623.66 3763.05 2693336 27536.04 51.57 41929.92 247.04 41682.88 PASS i 10000.00} 8285.96 1023.16 -5170.11 3686.97 3825.52 26943.64 27536.40 51.60 41970.02 24836 41721.66 PASS 10100.00} 8374.26 1031.63 -5216.27 3828.92 3965.63 26966.43 2753730 51.63 42010.07 249.83 4176024 PASS 10200.001' 8462.56 1040.10 -5262.43 3891.38 4027.31 2697626 27537.84 51.67_ 42050.13 251.15 41798.98 PASS r 10300.001' 8550.87 104837 -5308.59 4161.59 4294.42 2701696 27540.77 51.67r 42089.84 25290 4183694 PASS 10400.00} 8639.17 1057.05 -5354.75 4203.51 4335.86 2702324 2754120 51.71 42129.62 254.18 41875.45 PASS 10500.00} 8727.47 106532 -5400.91 4271.83 4403.39 2703335 27541.92 51.75 42169.49 25531 41913.98 PASS 10600.00} 8815.78 1073.99 -5447.07 4335.52 4466.35 27043.19 27542.60 51.79 42209.42 256.84 4195238 PASS 10700.00} 8904.08 1082.46 -5493.23 4395.93 4526.05 2705239 2754326 51.83 42249.42 258.16 4199126 PASS 10800.00} 8992.38 1090.93 -5539.39 4439.71 4569.32 27059.05 27543.781 51.87 42289.51 259.44 42030.07 PASS 10900.00} 9080.69 1099.41 -5585.55 4482.16 4611.28 27065.47 275443 i8 51.91, 42__329.71 260.72 42068.99 PASS 11000.001 9168.99 1107.88 -5631.71 4713.91 4840.39 27100.15 27547.66' 51.93742369.87 262.44 42107.43 PASS 11100.001 9257.29 1116.35 -5677.87 4751.29 4877.35 27105.75 27548.13 51.97 42409.90 263.71 42146.19 PASS €8 35 • S as Clearance Report Cook Inlet EnergyOlson2 ro4 BAKER - - Closest estApprroach Page 24 of 25 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) We II Olson 2 Field Olson Creek Unit Wellbore Olson 2 WellPlan Facility Olson Creek CLEARANCE DATA-Offset Wein)ore:Otter#1 Offset Wellpath:Otter#1<0-5686> Facility:Otter Slot Otter#1 Welk Otter#1 Threshold Vahe=O.t)ft f=brterpolated/ectrapolated station Ref MD Ref TVD Ref North Ref East Offset MD OifsetTVD Offset North OffsetEast Hartz C-C ACR Ellipse ACR [ft] [It] [R] lit] [R] St] (ft] [R] Bearing Clear Dist MASD Sep Status P] lnl [R] Fit] 11200.00} 9345.59 1124.82 -5724.03 4788.64 4914.2;5- 27548.58 52.01 42450.05 264.98 42185.07 PASS 11300.00} 9433.90 1133.29 -5770.20 4869.58 4994.24 27123.79 27549.60 52.05 42490.30 26636 42223.93 PASS 11400.00} 9522.20 1141.77 -5816.36 4970.98 5094.47 27139.13 27550.97 52.08 4253053 267.79 42262.74 PASS 11500.00} 9610.50 1150.24 -5862.52 5088.54 5210.67 27156.88 27552.51 52.11 42570.74 269.26 42301.48 PASS 11600.00} 9698.81 1158.71 -5908.68 5133.74 5255.33 27163.78 27553.04 52.15 42610.97 270.56 42340.41 PASS 11700.00} 9787.11 1167.18 -5954.84 5170.91 5292.05 2716958 27553.44 52.19 4265132 271.83 42379.49 PASS 11800.00} 9875.41; 1175.65 -6001.00 5204.65 5325.36 27174.93 27553.78 52.23 42691.79 273.09 42418.69 PASS 11900.00} 9963.72 1184.13 -6047.16 5226.05 5346.48 2717838 27553.99 52.27 4273239 27433 42458.07 PASS 11967.90 10023.67 1189.88 -6078.50 5240.56 5360.80 27180.75 27554.13 52.30 42760.05 275.16 42484.89 PASS POSITIONAL UNCERTAINTY- offset Wellbore:Otter#1 Offset Wellpath:Otter#1<0-5686> Slot Surface Uncertainty@iSD Horizontal 2.000f Vertical 1.0001t Facility Surface Uncertainty @1 SD Horizontal 20.000ft Vertical 3.000ft HOLE&CASING SECTIONS-offset Wellbore:Otter#1 Offset Wellpath:Otter#1<0.5686> StrIng/Diarneter Start MD End MD Interval Start TVD End TVD Start N/S Start E/W End N/S End ENV [n] In] lit] [ffI [111 [t] [ff] In] [it] 10.75in Conductor 0.00 157.00 157.00 149.15 306.14 16301.711_ 16830.08 16301.99 16829.89 lin Casing 0.00 2092.00! 2092.00 149.15 2240.13 16301.711 16830.08 16316.65 16817.96 4.5in Casing 0.00 5686.001 5686.00 149.15 5798.95 16301.711 16830.08 16459.92 16814.22 €1 36 • • tea Clearance Report 11,411111 Olson 2r BAKER _ Cook Inlet Energy Closest Approach Page 25 of 25 HUGHES REFERENCE WELLPATH IDENTIFICATION Operator Cook Inlet Energy Slot Olson 2 Slot Area Cook Inlet,Alaska(Kenai Peninsula) Well Olson 2 Field Olson Creek Unit Wellbore Olson 2 WeliPlan Facility Olson Creek WELLPATH COMPOSITION-Offset Wellbore:Otter#1 Offset Wellpath:Otter#1<0-5686> Start MD End MD Positional Uncertainty Model LogName/Commmt Wdmare 10.00 5686.00 Generic gyro-continuous(Drillpipe) Otter#1 GMS(200.5686) I Otter#1 OFFSET WELLPATH MD REFERENCE- Offset Wellbore:Otter#1 Offset Wellpatb:Otter#1<0-5686> MD Reference:Miller Rig#34(RTE) Offset TVD&local coordinates use Reference We/Oath settings (See WELLPATH DATUM on page l of this report) Ellipse Start MD 324.40ft €8 37 Olson Creek 2 Analysis Surface Location: 2593'FWL,2931' FNL, Sec 6, T13N, R1OW SM N 61 14'44.259",W 151 08' 11.361" (NAD 27 ASP Z4) N 2,648,980.00', E 299,832.00' Bottom Hole Loc: Estimated 1750' FWL, 1800' FNL, Sec 1, T13N, R11W SM 61 14'54.919" N, 151 10' 15.999" W (NAD 27 ASP Z4) N 2,650,170', E 293,754' Surface Elevation: —291.5 feet Estimated Drill Floor/KB: —17.4 feet/-308.9 feet Formation Tops (Estimated) Lower Sterling -200' and (Depths Estimated) Beluga 2,420" and/2,082' tvd (Depths Estimated) Upper Tyonek 7,820' and /6,345' tvd (Depths Estimated) Chickaloon 9,350' and /7,800' tvd (Depths Estimated) Well Description: Well is intended as a deviated grassroots exploration well to test the potential of the lower Beluga and Tyonek gas intervals. Primary completion is expected to be confined to the Beluga and Upper Tyonek intervals. Geology The Olsen Creek area is situated along the west/northwest flank of the Upper Cook Inlet Basin. The northeast trending structure appears to be set up along a northeast trending fault system, likely of transpressional origin, which is responsible for the development of the Three Mile Creek Field to the south-west of the Olson Creek prospect, as well as the Lone Creek Structure to the east of the Olson Creek prospect. This unnamed fault system is parallel and subordinate to the Bruin Bay Fault located further to the West/ Northwest of the location area, 38 • M and is generally considered the principal basin bounding fault in this portion of the basin. West of the Bruin Bay Fault, the Tertiary section of interest thins substantially. These sandstones were deposited in a variety of continental depositional systems, ranging from anastomozing stream channels and alluvial fan complexes, to axial meandering to braided fluvial environments. The provenance area is characterized by a magmatic arc; which contributed an immature quartz +feldspar+volcanic lithic assemblages. The formations expected at the Olson Creek Location are as follows: • Sterling Fm. (Late Miocene) If present, it may be very thin. Porosities range from 25%-30%, with permeabilities — 100-500 md; The formation contains abundant volcanic rock fragments sourced from west; Mainly contains biogenic gas from interbedded coals; lower contact unconformable; Capped by glacial alluvium, so top seal can be an issue. • Beluga Fm. (Late Miocene) Porosities range from 17-24%, with permeabilities —50-400 md; Mainly claystones with thin interbedded sandstones, occasional gravels and lots of thin coals; usually contains biogenic gas from interbedded coals; Sands deposited in streams channels. • Tyonek Fm. (Early Oligocene — Late Miocene) Porosities range from 14-21, with permeabilities fro K— 40-100 md. Rocks were deposited in series of anastomozing stream channels with more and thicker coals than overlying Beluga Fm; Tyonek usually contains biogenic gas from coals. Geologic Hazards: Coals present in Tyonek Fms that tend to slough off and swell into the hole and are responsible for numerous stuck bits in previous wells. Coals are also present within the Beluga Fm although not as prevalent or as thick as in the Tyonek. Care should be exercised for sloughing coals, differential sticking and/or lost circulation when drilling the Tyonek Formation. Evaluation of surrounding wells and several seismic lines across the proposed location do not indicate any shallow gas hazards present and no abnormal pressures are 39 • • anticipated. Drilling practices are posted for proper procedures on preventing and handling any gas kicks due to swabbing. Logging Services: Mud Logging services will be done by Canrig and commence after conductor pipe has been set(Gas detection to TD of well). 2 sets of dried and 1 wet samples will be collected every 30' to TD of well. Samples should be increased to every 10' if lithologies and gas detection warrant. 40 BOP & Diverter Sketch Operator: Cook Inlet Enemy Date: 5-Sep-12 _ L 24' I 286"I Bell Nipple 21-1 14" Hydrll"MSP" I16"Diverter Line with Hydraulic Actuated Full Opening Valve imansuimin 1[111uh1111111 mdeuram 20" 12 1/4" 41 • . BOPE Schematic Operator: CIE, Patterson UTI Rig No.191 Date• 4-Jun-13 I Component Height" Annular 49.25 Double U 66.67 Drlg Spool +/-36" C0.4."."...."."s. Single U 41.69" Total: 193.61" Cameron D (Top of 13 sir 5M x 10M DSA=GL) 13-57 1t7M Cameron U rrwrga" ;.■� Imo- 3 112"x 5"VBR i i) 3-1116",IOM,Kill Line ,. -- Blind Rams FireRatedHose ■R : ) 11111 as ....9.1Mud Cross has 4-1/16",10M Oual 1A 13-5/8"10M i �i 4-1/16",10M,Kil1Line II - .�>:I+ :II III II 'Mil Fire Rated Hose zr 13-5/8"10M N 3-1/16",IOM GateValves Cameron U 4.1116"HCR Gate Valve 3-1/16",10M x 4-1/16",10MD + 12 4.1116",IOM Gate Valve col • I 3112"x5"VBR Olt MI Maki& 13.5/8.1 Illi 5Mx 101:1 (..._ 1 1 i, i - 1 ; •, el I' . E (,— 2.1/16",5M,Gate Valve �= j � `,,I:- I. Z-1/10",5M,Coe Valve . 42 ! i pi PATTERSON-UTI TYPE E - 10M Choke Manifold Well Control 77, ) 1 I , _i •,* J i00x 1-. I. . . I-7 / 0 c=,4=0 ,s Or.., .tri / I I n OO !` -- y�� -�� Q.OO r. 4 _ �. !I/ a. v� •.v .iz Il' vi•?i — doh •_ z .X. 0 0 0 0 Q 14 PM-334 4 1/16" 10M Manual Gate Valves 4 1/16" 10M Manual Choke Valves Valve® thru ,o TYPE Cameron. Valve® and 73 TYPE Cameron. 2 1/16" 10M Manual Gate Valve 3 1/16"10M Willis M-3 Remote Choke Valve® TYPE Cameron. Valve® TYPE Cameron. 43 0 • Wellhead Schematic .106 GE Oil &Gas I 47.T -,(3`i i C.I )1 0.111"- Z-Wlr 611 I�.p 11111111 - rpt - - Ix • 11.r )O 7 i,- 211111r ID .a..,_......1 likii Aar LC7 z9nr.. _` 194 , 8' ` ,,,,,,N=..-7,---____. 1P 9" -/... i 1 I., u, 78.rna 19 Ir U la'S ' ._� i•�I�i I rim- !I T ,,! sh...0 ill= '_ - E.�" 1r 9tdima9-1n0.B4 Ill illo �.I yy99Bba 99! ill tr znnraa i , 989 Owing r o.r„ 1N•Lv.ol lr.1.LI VP coi,4 Lbw 2-7/11.Tubing ALL DIMENSIONS ARE APPROXIMATE TN..nrea.p.ere property ofOE 01 IL G..Pr.....Coes LP..f..murdered oonrwo.lUnless anaw.".waned.,".em, COOK INLET ENERGY,LLC rWw It nor b tt..1.n.e.y..used.copied,aa....ia9a Cr nvloaua.d except far 9Me sole purpose/f GE 014 Ge.Pne.u..G.l1M LP. OLSEN#2 9-5/8"x 7"x 2-7/8"5M SH2 Conventional Wellhead Assembly, °RAVVN CR 09JUL14 APPRV With T-M40-CCL Tubing Hanger and Adapter Flange FOR REFERENCE ONLY With 09JUL14 DRAWING NO. 1001348 44 • • GeoMechanical Plot- Calc Pore Olson Creek Proposed Geo Mechanical Plot Pressure Equivalent Mud Weight(PPG) 8 10 12 14 16 18 20 0 Sterling+/-200' Mud 13 3/8" Weight 1000 (Pore Press. + Drilling 9 5 " margin) 2000 — -- in Frac Gradient Beluga +1-2410' M +/-2074' /D 3000 F, 4000 z ai 5000 I — 6000 7000 --___._ 7 ' 8000 T onek+ -7778' D -6325'IVD 5 " 9000 -- — 45 • 40 i Casing Program Cook Inlet Energy Casing Plan WELL NAME: Olson Creek 2 Well Information ENGINEER: Courtney Rust DATE: 17-Jun-14 Max EMW Estimated Hole Sizes Casing Size Estimated Range-Mud MD(ft) TVD(ft) (Pore Frac Grad at Mud Type Comments (in) (in) Weight(ppg) Pressure) Shoe 13 3/8" — — -- — — Conductor pipe 12 1/4" 9 5/8" 2,000 1,781 8.9 15.2 8.8 9.2 WBM Norm grad Based on offests 8 1/2" 7" 7,500 6,089 9.8 15.8 8.8 9.8 WBM I 6 1/8" 5" 11,967 10,024 10.2 15.8 8.8 10.5 WBM Casing Plan 'ENTER YELLOW CELLS MANUALLY Connection API rating Casing Size Wt lb ftGrade MD(ft) ND ft (in) ( / ) Type OD(in) Burst(psi) Collapse Tension ( ) (psi) (kips) 13 3/8" 68 L80 BTC -- — -- — 0 0 9 5/8" 40 L80 BTC 10.625 6870 5750 1161 2000 1781 7" 26 1.80 BTC 7,875 7240 5410 641 7500 6089 5" 18 L80 BTC 10140 10500 457 11967 10024 Variables&Formulas Wellhead 5,000 psi Gas Gradient 0.10 psi/ft Pore Pressure Gradient 0.460 psi MAWP=(0.80 X CASING BURST)or Limiting Wellhead Pressure MASP=Lessor of(Frac Pressure t a(0.052 X(MW+0.5ppg SF)X TVD)-GasGRD X TVD)) or(Max Pore Pressure-(GasGRD X ND)) MASCP=(0.80 X CASING BURST)-(MW-Backup FluidWt.)X.052 X ND SF Burst=Burst Value/MASP SF Collapse=Collapse Value/((0.052 X Max EMWPore Pressure X ND)-(gas gradient X TVD)) SF Tension=Tension Value/(Length X lb/ft) 46 • 110 Max Allowable Working Pressure MAWP=(0.80 X CASING BURST)or Limiting Wellhead Pressure Hole Sizes Casing Size Safety Wellhead MD(ft) ND(ft) Burst(psi) MAWP(psi) (in) (in) Factor (psi) 12 1/4" 9 5/8" 2,000 1,781 6870 0.8 5,000 5496 81/2" 7" 7,500 6,089 7240 0.8 5,000 5792 6 1/8" 5" 11,967 10,024 10140 0.8 5,000 8112 Max Anticipated Surface Pressure MASP=Lessor of(Frac Pressure @(0.052 X(MW+0.5ppg)X TVD)-GasGRD X TVD))or (Max Pore Pressure-(GasGRD X ND)) Hole Sizes Casing Size Max EMW Frac Grad at MW Safety Gas Frac Max PP at MD(ft) ND(ft) Pressure at MASP(psi) (in) (in) (ppg) Shoe Factor Gradient Next TVD Shoe 12 1/4" 9 5/8" 2,000 1,781 8.9 15.2 0.50 0.10 1276 2,209 1,276 81/2" 7" 7,500 6,089 9.8 15.8 0.50 0.10 4552 4,106 4,106 6 1/8" 5" 11,967 10,024 10.2 15.8 0.50 0.10 7494 4,314 4,314 Max Allowable Surface Casing Pressure MASCP=(0.80 X CASING BURST)-(MW-Pore Pressure)X.052 X TVD Max EMW Hole Sizes Casing Size Safety (in) (in) MD(ft) ND(ft) Burst(psi) Factor MW (Pore MASCP(psi) Pressure) 12 1/4" 9 5/8" 2,000 1,781 6870 0.8 9.2 8.9 5468 8 1/2" 7" 7,500 6,089 7240 0.8 9.8 9.8 5792 6 1/8" 5" 11,967 10,024 10140 0.8 10.5 10.2 7956 Safety Factors Hole Sizes Casing Size Collapse Tension Liner Length SAFETY FACTORS MD(ft) ND(ft) Burst(psi) Wt(Ib/ft) (in) (in) (psi) (kips) (ft) Burg Collapse Tension 12 1/4" 9 5/8" 2000 1781 6870 5750 1161 40 - 5.4 8.9 14.5 8 1/2" 7" 7500 6089 7240 5410 641 26 - 1.8 2.2 3.3 6 1/8" 5" 11967 10024 10140 10500 457 18 4767 2.4 2.4 5.3 SF Burst=Burst Value/MASP SF Collapse=Collapse Value/((0.052 X Max EMWPore Pressure XTVD)-(gas gradient X TVD)) SF Tension=Tension Value/(Length X lb/ft) 47 • • Drilling Fluid Program Mi SWACO Cook Inlet Energy,LLC Olson Creek#2 Fluids Program Proposal Summary Olson Creek#2 is a deviated grassroots exploration well that will be drilled utilizing Patterson Rig#191.The objective of the Olson Creek#2 is to test the potential of the lower Beluga and the Tyonek gas intervals. It is proposed that a M-I GEL Spud Mud system be utilized for the 12.25"surface hole section to 2,000'MD.In order to minimize the need of having large quantities of product on hand and also reduce the amount of cuttings that need to be hauled away, it is suggested that a highly inhibitive KLA-SHIELD system be used to drill the 8.5" intermediate interval to 8,500'MD The KLA-SHIELD system will be comprised of 3%KCL and sized Calcium Carbonate.The 6.125"production interval will also utilize the KLA-SHIELD system and be drilled down to 11,967'MD. Contingency products will be on hand to cover events such as mud weight increases and to combat any lost circulation problems that may occur. Footage Depth Mud Weight Casing Size Hole Size Casing Intervals Depth MD TVD of Hole Mud System _ Drilled (PPM 13.375" NIA ',t. 200' 200' NIA NIA NIA 9.625"OD 12.25" 0.1458 2,000' 1,781' 1,980' Gel Spud Mud 8.8.9.2 8.681"ID bblslft 85 7.0"OD 6.184"ID 0.0702 1 8,500' 6,961' 6,500' Kla-Shield 9.0.9.5 bblsft r r r 6.125" 5.V OD 4.27V ID 0364 11,967' 10,024' 3,468' Kla-Shield 9.5.10.5 bblsi t 48 • 12.25"INTERVAL SUMMARY SURFACE INTERVAL Drilling Fluid M-I GEL Spud Mud System Key Products M-I GEL,GELEX Bentonite Extender,POLYPAC SUPREME UL&Soda Ash Solids Control Shakers,Centrifuge Potential Problems Hole Stability Shallow Gas Washout Swelling Clays INTERVAL MUD PROPERTIES Depth MD(ft) Mud Wt. Funnel Viscosity Plastic Viscosity Yield Pointllb/100ft API Fluid Loss LOS(%) (PPO) 7) (ml/30min) 0'-2,000' 8.8-9.2 85-125 20-40 25-45 <9 <13% NOTE:This program is provided as a guide only. Well conditions will always dictate fluid properties and product additions required for well-bore integrity. Surface Interval Overview Lithology through this zone is a composite of sand and small pea gravel in the upper intervals with a grading downward to predominately sand and some siltstone in the lower zones of this interval. Based upon work done on previous wells in this area,an M-1 GEL Spud Mud is recommended for the surface interval. Table 4.1:Initial Fluid Makeup for M-1 GEL Spud Mud(use fresh water) PRODUCT CONCENTRATION M-I GEL 25-27 lb/bbl Soda Ash 0.25-0.5 lb/bbl or as needed GELEX As needed(do not add until drilling out conductor) Table 4,2:M-1 GEL Spud Mud Additions PRODUCT CONCENTRATION M-I GEL 25-27 lb/bbl Soda Ash 0.25-0.5 lb/bbl oras needed Caustic Soda As needed for a pH of 9.0-9.5 GELEX As needed for viscosity POLYPAC SUPREME UL 0.25 lbs/bbl or as needed to control fluid loss 49 • • 6.125" Interval Summary PRODUCTION INTERVAL Drilling Fluid System KLA-SHIELD Key Products POLYPAC SUPREME UL,DUO-VIS,KCL,KLA-STOP,Busan 1060,DEFOAM-X,ASPHASOL SUPREME,LOTORQ,DRILLZONE,SAFE CARB-20,SAFE CARB-40,M-I WATE,SACK BLACK,CONQOR 404WH&RESINEX Solids Control Shakers&Centrifuge Potential Problems Hole cleaning Loss circulation/Differential sticking Hole stability Running coals INTERVAL MUD PROPERTIES Depth MD(ft) Mud Wt. PV Yield Point HTHP Fluid Loss Cl- LGS (ppg) (Ib1100ft2) (1b1100ft2) (m1130min) (mgli) (%) 8,500-11,967' 9.5-10.5 10-20 15-25 <8 14,000-18,000 <6% NOTE:This program is provided as a guide only.Well conditions will always dictate fluid properties and product additions required for well-bore integrity. Production Interval Overview The production interval will be drilled to a depth of 11,967'MD using a 6.125"bit with the highly inhibitive KLA- SHIELD system at 10.5ppg containing 3%KCL.Wellbore stability is crucial to the interval as several coal seams will be drilled.A well maintained mud system supplemented with good solids control equipment for maximum solids removal will minimize fluid invasion.Proper drilling practices and properly engineered fluid will minimize wellbore instability. Any new fluid that is required should be built to the below specs. KLA-SHIELD Drilling Fluid Formulation: Fresh Water 0.88 bbls DUO-VIS 1.0 ppb(as needed for Rheology) POLYPAC SUPREME UL 1.5—3.0 ppb 3% KCI 10.7 ppb(in base brine) M-I WATE As needed for density KLA-STOP 8.0-12 ppb/2.0—3.0%v/v DRILZONE 0%-2.0%As needed Busan 1060 0.49 ppb 50 • • Logging Plan Wireline logging will be open hole (Weatherford) Shuttle Conveyed Quad combo (Gamma-Ray, Neutron, Density, Microlog, Cross dipole sonic, and Resistivity) and logged pulling out of the hole. Mud Logging Plan Mud loggers will catch 30' ditch samples and maintain a wet and dry cut. Samples to be sent to state as required by regulations. Mud logging to commence in 8 ''A" hole immediately below the 9 5/8" casing shoe at 2000'. Solids Control and Equipment Item Equipment Specifications Shakers Brandt King Cobra Triple Shaker Desander 3 cone desander Desilter 24 cone desilter Centrifuge TBA Drilling Waste Storage Drilling wastes will be either granular solids (cuttings), or liquids (drilling mud or water). Cuttings and fluids will be stored in a permitted disposal pool and transferred to super sacks for disposal at the West MacArthur grind and inject facility. 51 • • Cementing Program Surface: FLUID SYSTEMS MUDPUSH II System MUDPUSH II Density — 11.001b/gal Total Volume 35.0 bbl AdditivesCode Description Concentration D031 _ _ Weighting Agent 3447.7 Ib/mgal Class A Extended Lead Slurry 136Q sacks,94 lb per sack of Blend) System Conventional Density 12.00 lb/gal Yield 2.44 ft3/sk _ Mix Water 14.329 gal/sk Mix Fluid 14.479 gal/sk Total Volume 157.0 bbl Cede Orion Concentration -- Class Class A Cement 94 Ib/sk WBWOB Additives 0110 Retarder 0.150 gal/sk VBWOC 0046 Anti-Foam 0.2%BWOB 0079 Extender 2.0%BWOB 0020 Extender 2.6%BWOB Class A Tail Slurry 1284 sacks,94 lb per sack of Blend) System Conventional Density 15.40 lb/gal Yield 1.22 ft3/sk Mix Water 5.507 gal/sk Mix Fluid 5.507 gal/ak Total Volume 61.6 bbl Cods Description Concentration Class A Cement 94 lb/sk WBWOB Additives 0046 Anti-Foam 0.2%BWOB 0065 Dispersant 0.4%BWOB 5002 CaCl2 0.2%BWOB H2O System Water Density 8.34 lb/gal Total Volume 5.0 bbl Additives Code Description Concentration 52 1 • Intermediate JOB AT A GLANCE Depth(TVD) 6,961 ft Depth(MD) 8,500 ft Hole Size 8.5 in Casing Size/Weight lin, 29 lbs/ft Pump Via T.O.D. (6.184".I.D) 29 Total Mix Water Required 833 gals Weighted Spacer Seal Bond 40 bbls Density 10.5 ppg Cement Slurry Class G 169 sacks Density 15.8 ppg Yield 1.15 cf/sack Displacement Drilling Mud 313 bbls 53 • WELL DATA ANNULAR GEOMETRY ANNULAR I.D. DEPTH(ft) (in) MEASURED I TRUE VERTICAL 8.681 CASING I 2,000 I 1,781 8.500 HOLE I 8,500 I 6,961 SUSPENDED PIPES DIAMETER (in) WEIGHT DEPTH(ft) O.D. I.D. (lbs/ft) MEASURED TRUE VERTICAL 7.000 6.184 29 I 8,500 6,961 Float/Landing Collar set @ 8,420 ft Mud Density 9.50 ppg Est.Static Temp. 126°F Est.Circ.Temp. 107°F VOLUME CALCULATIONS 1,000 ft x 0.1268 cf/ft with 40% excess = 177.5 cf 80 ft x 0.2086 cf/ft with 0% excess = 16.7 cf(inside pipe) TOTAL SLURRY VOLUME = 194.2 cf 35 bbls FLUID SPECIFICATIONS Weighted Spacer 40.0 bbls Seal Bond+110 lbs/bbl Barite-Sacked 10.5 ppg VOLUME VOLUME FLUID CU-FT FACTOR AMOUNT AND TYPE OF CEMENT Cement Slurry 194 / 1.15 = 169 sacks Class G Cement+0.005 lbs/sack Static Free+0.2%bwoc R-3+0.3%bwoc CD-32+0.5% bwoc FL-62+ 1 gals/100 sack FP-6L+43.7% Fresh Water Displacement 312.8 bbls Drilling Mud CEMENT PROPERTIES SLURRY NO.1 Slurry Weight (ppg) 15.80 Slurry Yield (cf/sack) 1.15 Amount of Mix Water (gps) 4.93 Amount of Mix Fluid (gps) 4.94 Production 54 • MUOPUSH II System MUOPUSH II Density 12.00 lb/gal Total Volume 35.0 bbl Additives Code Description Concentration D031 Weighting Agent 4748.2 lb/mgal EASYBLOK Production Slurry(350 sacks,94 lb per sack of Blend) System Conventional Density 15.30 lb/gal Yield 1.35 ft3/sk Mix Water 5.937 gal/sk Mix Raid 5.937 gal/sk Total Volume 85.7 bbl Expected Thickening Time 100 Bc at 05:24 hymn Expected ISO/API Fluid Loss 13 mL in 30.0 min Code Descii en Concentration G Cement 94 lb/sk WBWOB D046 Anti Foam 02%BWOB Additives D202 Dispersant 1.0%8W08 D400 Gas Control Agent 0.8%8W08 0154 Extender 8.0%BWOB D174 Expanding Agent 1.0%BWOB 0198 Retarder _ 0.2%BWOB H2O System Water Density 8.34 lb/gal Total Volume 5.0 bbl Additives Code Description Concentration 55 • i HA►.J uRToty ,. 12-114" (311 mm) FX56M PRODUCT SPECIFICATIONS Cutter Type X3-Extreme Drilling IADC C ode M222 jr ,. BodyType MATRIX Total Cutter Count 46 Cutter Distribution 132a1/ 16 ins MIME Face 0 0 30 Gauge 5 5 1 * _14 l'in ir' Up Drill 5 0 0 t Number of Large Nozzles 5 e Number of Medium Nozzles 0 ''-a ire Number of Small Nozzles 0 re- Number Number of Micro Nozzles 0 1r Itr Number of Ports(Size) 0 :° 41' :IP 1✓r ' Number of Replaceable Ports(Size) 0 Junk Slot Area(sgin) 28.02 iP * , Normaliz edF ace V olume 51.21% e" 'x, API Connection 6-518 REG.PIN ,%v Recommended Make-Up Torque* 37,119—43,525 F t*lb s. <,,." N aminal Dimensions** *1:° Make-Up Face to Nose 14.92 in-379 mm Gauge Length 4 in-102 mm Sleeve Length 0 in-0 mm Shank Diameter 8.75 in-222 mm Break Out Plate(MatWLegacyie) 181955144050 Approximate Shipping Weight 420Lbs.-191Kg. SPECIAL FEATURES • Impact Arrestors,1/32"Relieved Gage,Up-Drill Cutters on Gage Pads,H ex agon TSP Gage Material#663911 *Bit specific eecommerded make-up torque is a function of the bit I.D.and actual bit sub O.D.utilized as specified in API RP7G S ectionA.82. **Design dimensions are nominal and may vary slightly on manufactured product.HallsburtoetDrill Bits and S ereices models am continuously reviewed and refired. Pmduct specifications may change without notice. ©2013 Halliburton All rights r eserved.S ales of Halliburton products and services will be in accord solely withthe terms and conditions contained in the contr actbetw een H alliburton and the customer that is applicable to the sale. v ww.hallibutton coat 56 I • HALLIBUIaTONi0 v 9.rwvr 8-112" (216mm) FX74D PRODUCT SPECIFICATIONS Cutter Type X3-Extreme Drilling t r IADC C ode M434 BodyType MATRIX TotalCutterCount 93 Cutter Distribution 13nn Face 67 s rt Gauge 19 + .r Up Drill 71_ e Number of Large Nozzles 0 I Number of Medium Nozzles 0 Number of Small Nozzles 6 Number of Micro Nozzles 0 Number of Ports(Size) 0 Number of Replaceable Ports(Size) 0 Junk Slot Area(sq in) 12.68 NormalizedFace V flume 39.67% r*w API Connection 4-1/2 REG.PIN a Re commended Make-Up Torque* 12,461—17,766 Ft*lbs. e• N aminal Dimensions** ;•." e•sR Make-Up Face to Nose 12.98 in-330 mm Gauge Length 4 in-102 mm Sleeve Length 0 in-0 mm Shank Diameter 6 in-152 mm Break Out Plate(Mat#/Legacy#) 181954/44040 Approximate Shipping Weight 170Lbs.-771(g. SPECIAL FEATURES Up-Drill Cutters on Gage Pads,Hexagon TSP Gage,OptimizedDual Row-"D"Feature Material#561050 *Bit specific seconnmended make-up torque is a Sanction of the bit I.D.aid actual bit sub O.D.utilized as specified in API RP7G S ection A.8.2. **Design dimensions are nominal and may vary slightly onmanofaetured product.Halliburton Drill Bits and S ervices models ane continuously reviewed ant refired. Product specifications may change without notice. ©2012 Halliburton All rights reserved.Sales of Halliburton products and services will be in accordsolelywiththe terms and conditions contained in the contract betw eenH elliburton and the customer that is applicable to the sale. www.hal lilturton.corn 57 • HALLI9 URTON ;,,•e::e.,,. 6-1/8" (156mm) MM64D PRODUCT SPECIFICATIONS Cutter Type S elecCCutter IADC C ode M434 '0 ", t '.' Body Type MATRIX X14 Total Cutter Count 55 44 A r Cutter Distribution l0 tr 13mm i; �1. �` l j Face 12 25 tit 1_16 Gauge 0 12 a `r ' Up Drill 0 6 +r. 'le ,00 " Number of Large Nozzles 0 Number of Medium Nozzles 0 "" Number of Small Nozzles 0 ,• &. Number of Micro Nozzles 6ar Number of Ports(Size) 0 elt ^+ Number of Replaceable Potts(Size) 0 I M Junk Slot Ar ea(sq in) 5.37 ) Norm alizedF ace V edume 2599% rse API Connection 3-112 REG.PIN s®to Recommended Make-Up Torque* 5,173—7,665 Ft*lbs. m e'r`g ji N ominal Dimensions** Make-Up Face to Nose 9.35 in-237 nun Gauge Length 2 in-51 ram it, Sleeve Length 0 in-0 rum Shank Diameter 4.5 in-114 mm Break Out Plate(Mat PLegacy#) 181953144030 Approximate Shipping Weight 90Lbs.-41Kg SPECIAL FEATURES Up-Drill Cutters onG age Pads,1/32"RelievedG age,Optimized Dual Row-"D"Feature Material#780706 *Bit specific recommended make-up torque is a function of the bit I.D.and actual bit sub O.D.utilized as specified in API RP7G S ectionA.8.2. **Design dimensions are nominal and may vary slightly onmanufactrred product.HalldrurbonDrill Bits and S ervices models are continuously reviewed and refined. Product specifications may change without notice. ©2013 Halliburton All rights reserved.Sales of Halliburton products and services will be in accord solely with the terms and conditions contained in the contractbetweenHallibueton and the customer that is applicable to the sale. www.ha llIburtdn.com 58 i • Regulatory Waiver and Special Procedures Requests AOGCC Regulation 20 AAC 25.235 Gas Disposition CIE requests permission to vent or flare gas from the WMRU-08 well test for a period of 14 days according to 20 AAC 25.235 d (6). Maximum anticipated daily flaring is expected to be 1MMSCF/D with a total expected not to exceed 10 MMSCF over the entire test. If the well is successful, it will be tied into the West McArthur production facility. AOGCC Regulation 20 AAC 25.265 Automatic shut-in equipment a well that is capable of unassisted flow of hydrocarbons to surface and that has an onshore surface location that is 660 feet or less of (A) a permanent dwelling intended for human occupancy, including a billeting camp or private residence; (B) an occupied commercial building, excluding a structure located within an existing oil or gas field; (C) a road accessible to the public; (D) an operating railway; (E) a government maintained airport runway; (F) a coast line measured at mean high water; (G) a public recreational facility; or (H) navigable waters as defined by the United States Army Corps of Engineers in 33 C.F.R. Part 329.4 with boundaries defined in 33 C.F.R. 329.11; The Olson#2 exploration well is located on a logging type road which is not considered as public access. Cook Inlet Energy does not intend to install a SSSV should the well be completed and requests confirmation from the AOGCC that it would also not consider the well road as a public access way. 59 • • Schwartz, Guy L (DOA) From: Schwartz,Guy I(DOA) Sent: Wednesday,August 20, 2014 10:49 AM To: 'Conrad Perry'; Stephen Ratcliff Cc: Courtney Rust Subject: RE:Olson Creek-02 Conrad, I agree that it adequate and will update the procedure in step#44. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226)or(Guy.schwartz@alaska.gov). From: Conrad Perry [mailto:Conrad.Perry(a)cookinlet.net] Sent: Wednesday, August 20, 2014 10:40 AM To: Schwartz, Guy L(DOA); Stephen Ratcliff Cc: Courtney Rust Subject: RE: Olson Creek-02 Thanks Guy,that was my edit, but I agree with you. We are estimating max pore pressure at TD of 10.2 ppg EMW and we need a minimum of 1 ppg kick tolerance. We will change the minimum FIT to 11.5 ppg EMW if that is acceptable. conrad From:Schwartz,Guy L(DOA) (mailto:guy.schwartzt alaska.gov) Sent:Wednesday,August 20,2014 10:01 AM To:Conrad Perry;Stephen Ratcliff Cc:Courtney Rust Subject:RE:Olson Creek-02 Courtney, I just noticed that the min FIT for the 7" shoe drillout is 10.5 ppg EMW. That seems low for adequate kick tolerance. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended 1 1111/11.- • • Bettis, Patricia K (DOA) <Courtney.Rust@cookinlet.net> Courtney Rust Sent: Wednesday, August 20, 2014 9:14 AM To: Bettis, Patricia K (DOA) Subject: Fwd: Legal Description for MHT 9300063 (Olson Creek#2) Attachments: MHT 9300063 Addendum No. 3 - Acreage Addition.pdf; ATT00001.htm Patricia, bottomhole is within MHT 9300063. We added a "Tract B"to the lease in January t 2013. I have attached the addendum to the lease which includes both the original lease description and the addition of the acreage where Olson Creek 2 will bottomhole,and includes the entirety of Section 1. Please let me know if you need more support. From: Bettis, Patricia K(DOA)" <patricia.bettis@alaska.gov> Date:August 19, 2014 at 8:09:38 PM CDT To: "courtney Rust (courtney.rust@cookinlet.net)" <courtney.rust@cookinlet.net> Subject: Legal Description for MHT 9300063(Olson Creek#2) Courtney, The proposed Olson Creek 2 well reaches total depth within Section 1,T13N, R11W, S.M. Does CIE have the lease for the entirety of Section 1? Is this bottom hole location within MHT 9300063? If so, I need a copy of the lease agreement and the legal description. (Looking at the legal description for MHT 9300062 from the Olson Creek 1 well, it appears that Section 1,T13N, R11W,S.M. is not within this lease.) Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It maycontain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or 1 • forwarding it,and,so that the AOGCC is aware of the mistake in sending to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 2 • • Bettis, Patricia K (DOA) From: Bettis, Patricia K(DOA) Sent: Tuesday,August 19, 2014 5:10 PM To: courtney Rust (courtney.rust@cookinlet.net) Subject: Legal Description for MHT 9300063 (Olson Creek#2) Courtney, The proposed Olson Creek 2 well reaches total depth within Section 1,T13N, R11W, S.M. Does CIE have the lease for the entirety of Section 1? Is this bottom hole location within MHT 9300063? If so, I need a copy of the lease agreement and the legal description. (Looking at the legal description for MHT 9300062 from the Olson Creek 1 well, it appears that Section 1,T13N, R11W, S.M. is not within this lease.) Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907)793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Tuesday, August 19, 2014 2:38 PM To: courtney Rust(courtney.rust@cookinlet.net) Subject: Olson Creek#2: Form 10-401 Good afternoon Courtney, Please resubmit the Permit to Drill Application-Form 10-401 on the current acceptable Form 10-401 (Revised 10/2012). This may be found at the following web address: http://doa.alaska.gov/ogc/forms/forms.html. Please resubmit the Form 10-401, only. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907)793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • Bettis, Patricia K (DOA) From: Courtney Rust <Courtney.Rust@cookinlet.net> Sent: Monday, August 11, 2014 12:09 PM To: Bettis, Patricia K (DOA) Subject: Olson Creek 2 Attachments: 143092-CIE Olson Creek No. 2 ASSTAKED NAD83.pdf; 143092-CIE Olson Creek No. 2 ASSTAKED NAD27.pdf Patricia, I believe you're also waiting on the plat for Olson Creek 2? Here it is. Thank you so much for your patience,we are working on a few internal issues to make our PTD process smoother since we are getting a little busier. Courtney Rust Cook Inlet Energy Drilling Engineer Cell: 907-350-0091 CONFIDENTIALITY NOTICE:This e-mail transmission and any document,files or previous e-mail messages attached to it,are confidential. If you are not the intended recipient,or a person responsible for delivering it to the intended recipient,you are hereby notified that any review,disclosure, copying,dissemination,distribution or use of any of the information contained in,or attached to this e-mail transmission is STRICTLY PROHIBITED. If you have received this transmission in error,please notify us immediately by forwarding this message to the original sender or by telephone at 907.350.0091 and then delete this message and its attachments from your computer. 1 • • Bettis, Patricia K (DOA) From: Courtney Rust <Courtney.Rust@cookinlet.net> Sent: Tuesday,July 22, 2014 4:19 PM To: Bettis, Patricia K (DOA) Cc: Ferguson,Victoria L (DOA) Subject: Re: Olson Creek#2: Permit to Drill Application Patricia, I'm terribly sorry. Obviously they did not submit the revised form. 9800' MD Productive Horizon: 2506.30' FEL, 1960.18' FNL, Sec 1,T13N, R11W SM (Y=2,649,986.32',X=294,754.64') BHL: 11,967MD/10024TVD: 3510.08' FEL, 1794.40' FNL,Sec 1,T13N, R11W SM (Y=2,650,170', X=293,754') We do not currently have a plat. We are having surface location work done and will get it surveyed and staked this week or next and we will have to submit a new 10-401 form with the change of surface location, however,we are approaching the spud date rapidly. Will this be a problem? Bottom hole pressure: 10,024*.455=4560 PSI Or with the gas gradient 10,024*.455-(.1*10,024)=3558 PSI I have differed the our land guys on the MHT permit. It has been extended, but I will get back with you on documentation. From:<Bettis>, "Patricia K(DOA)" <patricia.bettis@alaska.gov> Date:Tuesday,July 22, 2014 7:11 PM To: Courtney Rust<courtney.rust@cookinlet.net> Cc: "Ferguson,Victoria L(DOA)" <victoria.ferguson@alaska.gov> Subject: Olson Creek#2: Permit to Drill Application Courtney, Thank you, the AOGCC received the revised 10-401 Form today. In reviewing the application, I have noted some missing information and have a question concerning pressures: 1. On the Form 10-401, Box 4a, information is missing for the "Top of Productive Horizon" and "Total Depth" locations. Please provide the footage from section line and township, range and section. 2. A property plat or As-Built survey for the surface location of the Olson Creek 2 well is missing from the application. 3. Provide the calculation for the maximum anticipated bottom hole pressure for the well. Using a gas gradient of 0.52 as provided on page 47,TVD of 10,024'ND and maximum pore pressure (EMW) of 10.2 ppg,we are unable to come up with the 4560 psi as stated in Box 17 of the 10-401 Form. 4. Has the term of the Oil and Gas Lease MHT 9300062 been extended and if so, please provide documentation. 1 Finally, the proposed wellbore survey Wellpath Geographic Report) is of such fine font that my OCR program cannot recognize the numbers and the survey cannot be put into the AOGCC database. Please submit this survey in an excel spreadsheet format. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential Conservation and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 2 • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Tuesday, July 22, 2014 4:12 PM To: courtney Rust (courtney.rust@cookinlet.net) Cc: Ferguson,Victoria L (DOA) Subject: Olson Creek#2: Permit to Drill Application Courtney, Thank you,the AOGCC received the revised 10-401 Form today. In reviewing the application, I have noted some missing information and have a question concerning pressures: 1. On the Form 10-401, Box 4a, information is missing for the "Top of Productive Horizon" and "Total Depth" locations. Please provide the footage from section line and township, range and section. 2. A property plat or As-Built survey for the surface location of the Olson Creek 2 well is missing from the application. 3. "PProovide the calculation for the maximum anticipated bottom hole pressure for the well. Using a gas gradient of .8..-ras provided on page 47,TVD of 10,024'TVD and maximum pore pressure (EMW)of 10.2 ppg, we are unable to come up with the 4560 psi as stated in Box 17 of the 10-401 Form. 4. Has the term of the Oil and Gas Lease MHT 9300062 been extended and if so, please provide documentation. Finally, the proposed wellbore survey(Planned Wellpath Geographic Report) is of such fine font that my OCR program cannot recognize the numbers and the survey cannot be put into the AOGCC database. Please submit this survey in an excel spreadsheet format. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907)793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • • Bettis, Patricia K (DOA) .1111 1111 , I, From: Bettis, Patricia K (DOA) Sent: Tuesday, July 22, 2014 9:44 AM To: courtney Rust (courtney.rust@cookinlet.net) Subject: Olson Creek#2: Permit to Drill Application Good morning Courtney, Per 20 AAC 25.055(c), Cook Inlet Energy needs to submit a discussion with supporting documents that the proposed well will not encounter abnormally geo-pressured strata to the proposed total depth of the well, or any potential shallow gas sources to a depth of 2,000 feet. 20 AAC 25.055(c)(9) For an exploratory well a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f). 20 AAC 25.055(c)(10) 20 AAC exploratory for an 25.061(a), p Y ex well, near surface strata to a depth of 2,000 feet(TVD) in the vicinity of the well must be evaluated seismically by common depth point refraction or reflection profile analysis to identify anomalous velocity variations indicative of potential gas sources. Will the wellbore cross any significant shallow fault, above 2,500' +1-TVD, which may provide a trap or seal for gas? Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • • Bettis, Patricia K (DOA) From: Bettis, Patricia K(DOA) Sent: Friday, July 18, 2014 2:48 PM To: courtney Rust (courtney.rust@cookinlet.net) Cc: 'Schwartz, Guy L (DOA) (guy.schwartz@alaska.gov)' (guy.schwartz@alaska.gov) Subject: Olson Creek#2: Permit to Drill Application Courtney, The application was submitted on an outdated Form 10-401 (Revised 7/2009). Please resubmit the Form 10-401 using the current form, i.e., Form 10-401(Revised 10/2012). This form can be found at the following link: http://doa.alaska.gov/ogc/forms/forms.html. Please review the information on the form for correctness. On the 10-401 form submitted surface pressure was greater that bottom hole pressure, and information was missing for"Top of Productive Horizon" and "Total Depth" locations (Box 4a). Have a great weekend, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettisPalaska.gov. 1 • • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. • • TRANSMITTAL LETTER CHECKLIST WELL NAME: LJLon 6..:i- a. .2 PTD: ,9,/'1 -1) 3 Development Service /Exploratory _Stratigraphic Test _Non-Conventional FIELD: 403..r.17POOL: Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit (If last two digits No. , API No. 50- - - - . in API number are Production should continue to be reported as a function of the original between 60-69) API number stated above. 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 Pilot Hole ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce / inject is contingent upon issuance of a Spacing Exception conservation order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. / All dry ditch sample sets submitted to the AOGCC must be in no greater �/" Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by ( olnh,— .r5 1 in the attached application, the following well logs are Well Lo ,n also required for this well: l4 'U c,,A,rv� iro, a- gg g c�n�.�u T 4o c lisw;♦.\44, l,5' l G J join. psLI 67 Ci E c,, ✓&-J y Cc... Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC / within 90 days after completion, suspension or abandonment of this well. Revised 4/2014 • 0 coTo m On 0 V 22 E iii O) L �, u) @ 7 '3, c' CD— TD c '' ° i Q a N N -° 0 7 c It 05 o c :1. a c °' U L 3 0.6 3; ,Q �, a�, m u) o . rn o co. 3 a. ° 4 co' a). 't a) a) m ca 5o o. ao rn ° w c o CA o ° a c o' c 0ts o N > a) - `m. °' 3 ri o o L n amici c c aai as C v 8- E a) E as. o E. co .0 a) L - � 'Cr)CD a o r o w ° ° o v o >, o° o ° ° th !IIh � f � ai Oc , . 0. , . a o) —' i— as 2as N (0 ry a� ° . �, us (N i3 o N oo LLIoM ,n z o N 0 m •.a a; o E o 'a O, N �, N; , of o 3 U oa ct m a Z C." I o N E U ac). 3' `o; t; 00 �, o', y, o 0E m, E m 0 = 3 m N O N 0 T. c rn n O, E Q a 0 :° u a = a o •5 m a o c n J °� .t Q a) ° a) c• p, H. U' a) n O> N cr N. Z V O o 7 _ Q U E -(7) . of > > u ° v) ° o = g ° a�, 0 0 N N *k Q) N L 1] 0) Q) C L. w. n a) N c c L n L' -0 B N N' '� y a) a) ai o m Y 3 0 = S v' w m Bi Ti 3 c 3 ° rn' rn' �' 3' 3 0' N c' a a� ra 3 o 0 .0 v N yr o m Z as a) C9 O C- 2O E N N O 7 0 C O O W o A E. 0. 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No special effort has been made to chronologically • organize this category of information. CCooookk IInnlleett EEnneerrggyy OOllssoonn CCrreeeekk ##22 88//2288//1144 -- 99//2255//1144 Section 6 – T13N - R10W, SM Upper Cook Inlet, Alaska April 23, FINAL WELL REPORT Lees Browne Jr – Senior Logging Advisor George Baker – Senior Logging Geologist Olson Creek #2 1 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT AND CREW.......................................................................................2 1.1 EQUIPMENT SUMMARY...............................................................................................2 1.2 PERSONNEL .................................................................................................................2 2 GENERAL WELL DETAILS...............................................................................................................3 2.1 OBJECTIVES.................................................................................................................3 2.2 WELL RESUME .............................................................................................................3 2.3 HOLE DATA...................................................................................................................4 3 GEOLOGICAL DATA.........................................................................................................................5 3.1 FORMATION / ZONE MARKER TOPS..........................................................................5 3.2 ZONE SUMMARIES.......................................................................................................6 3.2.1 Surface Casing 155’ to 2023’..............................................................................................6 3.2.2 Intermediate Casing: 2023’MD to 8480’MD .......................................................................7 3.2.3 Production hole: 8480’ MD to 11589’ MD...........................................................................9 3.3 WELL LITHOLOGY......................................................................................................12 3.4 SAMPLING PROGRAM AND DISTRIBUTION ............................................................36 4 DRILLING DATA..............................................................................................................................37 4.1 DAILY ACTIVITY SUMMARY.......................................................................................37 4.2 SURVEY DATA............................................................................................................41 4.3 MUD RECORD.............................................................................................................44 4.4 BIT RECORD ...............................................................................................................46 5 SHOW REPORTS...........................................................................................................................47 6 DAILY REPORTS............................................................................................................................48 Enclosures: 2”/ 100’ Formation Log (MD and TVD 2”/ 100’ LWD Combo Log (MD and TVD) 2”/ 100’ Gas Ratio Log (MD and TVD) 2”/ 100’ Drilling Dynamics Log (MD and TVD) Final Well Data on CD Olson Creek #2 2 1 MUDLOGGING EQUIPMENT AND CREW 1.1 EQUIPMENT SUMMARY Parameter Equipment Type And Position Total Downtime Comments Ditch Gas Electric Driven QGM Gas Trap Mounted In Possum Belly; FID Total Hydrocarbon Analyzer And Chromatograph 0 Rate of Penetration (ROP) Pason Wits feed 0 Pump stroke counter Pason Wits feed 0 Hook load / Weight on bit (WOB) Pason Wits feed 0 Drill string torque Pason Wits feed 0 Top drive rotary (RPM) Pason Wits feed 0 Standpipe Pressure Pason Wits feed 0 Casing Pressure Pason Wits feed 0 Mud flow in / out (MFI / MFO) Pason Wits feed 0 Pit volumes Pason Wits feed 0 Driller’s work station Pason 0 Company Man’s work station Pason 0 Tool pusher’s work station Pason 0 Mud Engineer’s work station Pason 0 Pits work station Pason 0 MWD / LWD WITS Feed WITS 0 1.2 PERSONNEL Unit Number: ML04 Mud loggers Years Days Technician Days Sample Catchers Days Lees F. Browne Jr 34 34 Omar Hinostroza 32 George Baker 40 34 Ishrat Farooqui 32 Olson Creek #2 3 2 GENERAL WELL DETAILS 2.1 OBJECTIVES Olson Creek #2 is a deviated grassroots exploration well to test the potential of the lower Beluga and Tyonek gas prone formations of the onshore Cook Inlet. Primary completion is expected to be confined to the Beluga and Upper Tyonek intervals. 2.2 WELL RESUME Operator: Cook Inlet Energy Well Name: OLSON CREEK #2 Field and Pool: Beluga River State: County Alaska Kenai Borough Company Representatives: Dimitry Smushkov, Rod Maniaci Location: SEC 6, T 13 N, R 10W SM Elevation: RKB 311.6’, GL 291.6’ Classification: Development Gas API #: 50-283-20174-00-00 PERMIT # 214-113 AFE #: 146001 Rig Name / Type: Patterson –UTI 191/ Land Triple Primary Target: Lower Beluga and Tyonek Gas intervals Spud Date :-> Finish Date :-> 8/28/14 9/25/2014 Total Depth: 11589’ MD /9656’ TVD Total Depth Formation: Tyonek Mud logging Company CANRIG DRILLING TECHNOLOGY, LTD MWD Company: Halliburton Tools Run: MWD: Dir, Gamma, Resistivity Directional Drilling: Halliburton Drilling Fluids Company: MI Swaco Olson Creek #2 4 2.3 HOLE DATA Maximum Depth Shoe Depth Hole Section MD TVD T.D. Formation Mud Weight (ppg) Deviation (oinc) Casing MD TVD F.I.T. 20” 117’ 117’ Sterling - 0 13 3/8” 117’ 117’ - 12 ¼” 2023’ 1790.45’ Sterling 9.5 49.43 9 5/8” 2023’ 1790.45’ 20.7 8 ½” 8480’ 10308’ U. Tyonek 9.5 30.13 7” 8487’ 6932’ 17.1 Olson Creek #2 5 3 GEOLOGICAL DATA 3.1 FORMATION / ZONE MARKER TOPS LWD tops refer to provisional picks by Cook Inlet Energy geologist. Projected (ft) LWD Tops (ft) Formation MD TVD MD TVD Sterling - - 250 250 Beluga - - 2260 1951 Tsuga 2-5 - - 3270 2744 Tsuga 2-6 - - 3840 3198 Tyonek - - 7318 5937 Chickaloon - - 11320 9430 Olson Creek #2 6 3.2 ZONE SUMMARIES 3.2.1 Surface Casing 155’ to 2023’ Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 412 1.1 131.3 35 1 4.6 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 1391 35 7046 59 14 - - - - SANDSTONE/CONGLOMERATIC SAND = DOM LOOSE GRAINS; CLEAR TO TRANSLUCENT GRAINS; DOM UPPER FINE TO UPPER MEDIUM GRAINED; TRACE BROKEN COARSE GRAINS; VARICOLORED GRAINS; DOM ANGULAR TO SUBANGULAR; LIGHT GREEN TO REDDISH GRAINS; MOD SORTED; TRACE ANGULAR CHERT; NO PRESERVED MATRIX; NO VISIBLE OIL INDICATORS. TUFFACEOUS SILTSTONE = MED TO LIGHT GRAY; VERY SOFT AND MUSHY; NO VISIBLE STRUCTURE; MASSIVE CUTTINGS; IRREGULAR FRACTURE; CLAYEY TO SILTY TEXTURE; GRADING TO TUFFACEOUS CLAYSTONE NON CALCAREOUS; VERY FINE SCATTERED CARBONACEOUS MATERIAL SANDSTONE = DOMINANTLY LOOSE GRAINS; SOME PRESERVED SOFT WHITE GRAY EXAMPLES; MUSHY IN PART; LOWER FINE TO UPPER MEDIUM GRAINED; MOD SORTING; ANGULAR TO SUBANGULAR; MOD TO POOR SORTING; LOW TO MOD SPHERICITY; SOME PRESERVED SILT/CLAY MATRIX MATERIAL; SME LIGHT GREEN GRAINS. TUFFACEOUS SILTSTONE = TAN; LIGHT BROWN; HARD; MASSIVE CUTTINGS; IRREGULAR FRACTURE; BROWN CLAY MATRIX; VERY FINE SILT TO LOWER FINE QUARTZ GRAINS; SILTY TEXTURE; DULL LUSTER; NO VISIBLE STRUCTURE; INTER BEDDED FINE CARBONACEOUS SHALE AND CARBON FINES; GRADATIONAL AND HYDROPHILIC. TUFFACEOUS CLAYSTONE = VERY LIGHT GRAY TO LIGHT GRAY; EVEN COLOR HUE VERY SOFT TO SOFT; MALLEABLE TO SECTILE; FLEXIBLE TO SUB ELASTIC; MUSHY TO PASTY; TACKY TO SLIMY; SLIGHT TO MODERATE COHESIVENESS; VERY ADHESIVE; EARTHY TO AMORPHOUS FRACTURE; AMORPHOUS TO MASSIVE HABIT WITH SUB NODULAR LARGE CUTTINGS FROM WELL BORE TRANSPORT; EARTHY LUSTER; CLAYEY TEXTURE; MINOR SILT INTERBEDDED WITH PYRO CLASTIC RELIC SHARDS IN MASS. COAL/CARBONACEOUS SHALE = DARK GRAY; DARK BROWN; SME TANISH HUES DULL EARTHY TO SLI RESINOUS LUSTER; HARD IN DARK GRAY SPECIMENS; BECOMING SOFT IN BROWNISH SPECIMENS; SLI PLATY CUTTINGS; IRREGULAR TO PLANAR FRACTURE; SOME THIN LAMINATIONS; SOME THIN MICRO PYRITE LAMINATIONS; SME BLEEDING GAS IN SAMPLES; DARK BROWN DOM CARB SHALE; LOW GRADE COAL; MINOR GAS INCREASES. Olson Creek #2 7 3.2.2 Intermediate Casing: 2023’MD to 8480’MD Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 375.2 .5 119.7 429 1 29.6 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 8024(Coal) 429 70910 328 23 13 - - - TUFFACEOUS SILTSTONE = MEDIUM LIGHT GRAY AND SUBTLE DIFFERENCES IN COLOR HUES; POOR INDURATION; OVERALL MUSHY; SLIGHTLY COHESIVE; SLIGHTLY TO MODERATE ADHESIVENESS WITH INCREASED CLAY CONTENT; EARTHY FRACTURE; SUB NODULAR HABIT FROM WELL BORE EROSIONAL TRANSPORT; SOME PDC GROOVED CUTTINGS FROM FIRMER CUTTINGS; MODERATE EARTHY LUSTER; SILTY TO CLAYEY TEXTURE; MASSIVE HOMOGENEOUS TUFFACEOUS SILTSTONE; COMPOSED OF 70% SILT, 20% CLAY, 10% VERY FINE GRAIN SAND INTERBEDDED. THIN BEDS OF PLATY VERY CARBONACEOUS SHALE ARE SCATTERED THROUGHOUT THIS SECTION. SAND/SANDSTONE (INTERBEDDED) = VERY LIGHT GRAY TO LIGHT GRAY; CLAST FROM FINE UPPER TO VERY FINE LOWER; SUB ANGUGLAR TO SUB ROUND; POOR SORTING; IMPACT TEXTURE; IMMATURE NATURE; VERY WEAK SILICIOUS CEMENT; DOMINANT GRAIN SUPPORT; SILT/ASH/CLAY MATRIX LOOSELY ATTACHED AND PORE FILLING; DETRITALISH; COMPOSED OF QUARTZ, SECONDARY CHERT, 20-30% SILICIOUS MUDSTONE, ARGILLITE W/ VARIOUS LITHIC DARK FRAGMENTS; SLIGHTLY CALCARIOUS; POOR POROSITY AND POOR PERMEABILITY; NO OIL INDICATORS SAND/SANDSTONE = DOM LOOSE QUARTZ GRAINS; ABUNDANT TRANSLUCENT TO CLEAR GRAINS; LOWER FINE TO UPPER FINE GRAINED; BECOMING LOWER MEDIUM GRAINED WITH DEPTH; DOM ANGULAR TO SUBANGULAR; LOW TO MOD SPHERICITY; TRACE MUSHY LIGHT GRAY CLAY MATRIX; TRACE BROKEN CHERT GRAINS; SOME LOOSE VARICOLORED GRAINS FROM LIGHT GREEN TO ORANGE TO REDDISH GRAINS; TRACE LOOSE LITHIC FRAGMENTS; ASSOCIATED WITH MINOR GAS INCREASES; NO FLUOR OR CUT. TUFFACEOUS SILTSTONE = MEDIUM LIGHT GRAY AND SUBTLE DIFFERENCES IN COLOR HUES; POOR INDURATION; OVERALL MUSHY; SLIGHTLY COHESIVE; SLIGHTLY TO MODERATE ADHESIVENESS WITH INCREASED CLAY CONTENT; EARTHY FRACTURE; SUB NODULAR HABIT FROM WELL BORE EROSIONAL TRANSPORT; SOME PDC GROOVED CUTTINGS FROM FIRMER CUTTINGS; MODERATE EARTHY LUSTER; SILTY TO CLAYEY TEXTURE; MASSIVE HOMOGENEOUS TUFFACEOUS SILTSTONE; MICRO LAMINATED CARBON CLAY WITH SOME PLANAR ORIENTATION @ 2400'; INCREASED VERY FINE GRAIN SAND INTERBEDDED @ 2460' COAL/CARBONACEOUS SHALE = BLACK MOTTLED BROWNISH BLACK; PARALLEL LAMINAR PATTERNS OF LIGHTER AND DARKER CARBON LAYERS; BRITTLE IN CARBON SHALE TO FIRM IN LOW GRADE COAL; EARTHY TO SUB RESINOUS LUSTER; PLANAR FRACTURE IN CARBON SHALE TO HACKLY IN COAL; PDC GROUND UP CUTTINGS; TRACE VISIBLE BLEEDS OF GAS FROM COAL ONLY; GRADING TO ASHY TUFFACEOUS SILTSTONE. Olson Creek #2 8 TUFFACEOUS SILTSTONE/CARBONACEOUS SHALE = LIGHT GRAY TO PINKISH GRAY (ASH); VERY POOR TO POORLY INDURATED; SLIGHTLY SECTILE WITH CLAY CONTENT ELEVATED; MUSHY, SLIMY; SLIGHTLY COHESIVE; SLIGHT TO MODERATE ADHESIVE; EARTHY FRACTURE; SUB NODULAR HABIT FROM WELL BORE EROSIONAL TRANSPORT; EARTHY LUSTER; SILTY TO ASHY TEXTURE; INCREASE IN ASH CONTENT @ 3510'; COMPOSED OF 70% SILT, 20% VERY FINE GRAIN SAND, PYRO CLASTIC RELIC SHARDS AND CARBON FINES; GRADING TO SILTY DEVITRIFIED ASH INTERBEDDED OR AS THIN BEDS; THIN LAMINAE OF CARBON SHALE. TUFFACEOUS SANDSTONE/DEVITRIFIED ASH = PINKISH GRAY TO PALE YELLOWISH BROWN; CLAST SIZE MEDIUM LOWER TO VERY FINE UPPER; SUB ANGULAR TO SUB ROUND; MODERATE DEVELOPED SPHERICITY; POOR SORTING; IMPACT TO CHIP TEXTURE; IMMATURE NATURE DOMINANT SILT/ASH MATRIX SUPPORT; PORE FILLING AND ACTING AS A LITHIFIYING AGENT; GRADING TO ASH AND LITHIC TUFF; POOR POROSITY AND VERY POOR PERMEABILITY; APPEARS REWORKED AND DEPOSITED; NO OIL INDICATORS. TUFFACEOUS SILTSTONE/CLAYSTONE = LIGHT GRAY TO MEDIUM LIGHT GRAY VERY POOR TO POORLY INDURATED; MUSHY TO PASTY; SLIMY IN PARTS; NON TO SLIGHTLY COHESIVE; SLIGHT TO MODERATE ADHESIVE; EARTHY FRACTURE; SUB NODULAR HABIT FROM WELL BORE EROSIONAL TRANSPORT; EARTHY LUSTER; SILTY TO CLAYEY TEXTURES; MASSIVE GRADATIONAL SILTS AND CLAYS WITH THIN TO THICK CARBON SHALE AND LOW GRADE LIGINITIC COAL WITH VISIBLE GAS BLEEDS SAND/TUFFACEOUS SAND = VERY LIGHT GRAY; CLAST SIZE MEDIUM LOWER TO VERY FINE UPPER; MEAN SIZE FINE; SUB ANGULAR TO SUB ROUND; MODERATE DEVELOPED SPHERICITY; GENERAL EQUANT GRAIN DIMENSIONS; MODERATE TO SOME POOR SORTING; IMPACTED TEXTURE; MATURE TO SUB MATURE NATURE; UNCONSOLIDATED CLEAN ARENACEOUS SAND TO WEAKLY CONSOLIDATED SANDSTONE GRADING TO TUFFACEOUS SAND WITH ASH MATRIX SUPPORT; GRAIN SUPPORT TO MATRIX SUPPORT: HETROGENEOUS; GOOD TO FAIR POROSITY AND PERMEABILITY; NO OIL INDICATORS COAL/CARBONACEOUS SHALE = BLACK MOTTLED BROWNISH BLACK AT CONTACTS AND GRAYISH BLACK AT MASS; FIRM TO HARD; EARTHY MOTTLED RESINOUS LUSTER; MATTE TEXTURE; BLOCKY TO HACKLY FRACTURE; DISTINCT VISIBLE BANDS OF DIFFERING CARBON MATURITY; VISIBLE BLEEDING GAS FROM MATURE COALS; APPEARS AS TWO THICK COALS WITH CARBON SILT AND TUFFACEOUS SILTSTONE BETWEEN SAND/SANDSTONE = DOM LOOSE QUARTZ GRAINS; DOM CLEAR TO TRANSLUCENT GRAINS; SME LIGHT GREEN TO WHITE TO LIGHT RED GRAINS; TRACE LITHICS; LOWER FINE TO LOWER MEDIUM GRAINED; ANGULAR TO SUBANGULAR; MOD WELL SORTED; LOW SPHERICITY; TRACE MATRIX SUPPORTED SPECIMENS WITH WHITE ASH; TRACE BLACK CARBONACEOUS SHALE BOUNDARIES WHICH IMPLIES INTERBEDDING WITH CARB SHALE CONTINUED VERY CLEAN UNCONSOLIDATED SAND TO 7585'; DOMINANT GRAIN SUPPORTED; ARENACEOUS; GOOD POROSITY/PERMEABILITY. COAL = BLACK; FIRM TO HARD; RESINOUS LUSTER; MATTE TEXTURE; HACKLY FRACTURE; COMPOSED OF CLEAN (NO CLAY) BITUMINOUS COAL; ABUNDANT VISIBLE BLEEDING GAS FROM MOST CUTTINGS; OCCURS AS MAIN BED WITH SECONDARY MINOR BEDS. Olson Creek #2 9 3.2.3 Production hole: 8480’ MD to 11589’ MD Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 347.5 .5 48.2 902 1 28.5 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 9609’(coal) 902 177099 791 188 - - - - TUFFACEOUS SILTSTONE = LT GRAY WITH BROWNISH HUES FROM MUD SYSTEM; SOFT; MASSIVE TO SLIGHTLY PLATY CUTTINGS EARTHY TO IRREGULAR FRACTURE; DULL EARTHY LUSTER; SMOOTH TO SILTY TEXTURE; VARIABLE AMOUNTS OF SILT; GRADING TO TUFFACEOUS CLAYSTONE; INTERBEDDED WITH THICK, BLACK, VITREOUS COAL F/8510' TO 8540'. VISIBLE BLEEDING GAS FROM COAL ASSOCIATED WITH GAS SHOW. CONGLOMERATE SAND/SAND/ASH = VERY LIGHT GRAY TO PINKISH GRAY/WHITE IN ASH; CLAST SIZE VERY COARSE LOWER TO FINE LOWER; ANGULAR BIT IMPACTED VERY COARSE TO COARSE GRAINS TO SUB ANGULAR TO SUB ROUND MEDIUM TO FINE GRAINS; LOW TO MODERATE DEVELOPED SPHERICITY; VERY POOR SORTING; BIMODAL WITH DEPARATE MODE PRIMARY MEDIUM/FINE GRAIN TO SECONDARY VERY COARSE TO COARSE; IMPACT TO CHIP TEXTURES; IMMATURE TO MATURE NATURE; UNCONSOLDIATED SAND WITH WHITE VERY SOFT DEVITRIFIED ASH BEDS DECREASING BY 8670' SAND IS GRAIN SUPPORTED WITH MODERATE ASH CONTENT OCCURING AS THIN BEDS OR POSSIBLE INTERBEDDED; POOR TO GOOD POROSITY AND PERMEABILITY; COMPOSED OF DOMINANT QUARTZ, SECONDARY CHERT, TRACE ARGILLITE (SILICEOUS MUDSTONE), FELDSPAR NO SHOW OIL OIL INDICATORS TUFFACEOUS SILTSTONE = LIGHT GRAY TO LIGHT BROWNISH GRAY (FROM MUD); BECOMING WHITE GRAY AT 8910'. SOFT AND POORLY INDURATED; MASSIVE TO SLIGHTLY PLATY CUTTINGS; SLIGHTLY ADHESIVE; EARTHY TO IRREGULAR FRACTURE; DULL EARTHY LUSTER; ASHY TO SILTY TEXTURE; ASH INTERBEDS; BECOMING SANDY WITH VERY FINE QUARTZ AT BASE; FINE CARBONACEOUS LAMINATIONS; INTERBEDDED WITH THIN BLACK TO BROWN CARBONACEOUS SHALE AND BLACK, VITREOUS COAL INTERVALS. TUFFACEOUS SANDSTONE/SAND = VERY LIGHT GRAY TO PINKISH GRAY; CLAST SIZE FINE LOWER TO VERY FINE LOWER; SUB ROUND; MODERATE TO WELL DEVELOPED SPHERICITY; MODERATE TO POOR SORTING; IMPACT TEXTURE; SUBMATURE TO MATURE NATURE; VARIOUS DEGREES OF TERRIGENOUS COMPONENTS; BOTH ASH/SILT (ABUNDANT) TO ARENACEOUS GRAIN SUPPORTED SAND IN THIN BEDDING; POOR TO GOOD POROSITY AND PERMEABILITY; NO OIL INDICATORS. SAND/TUFFACEOUS SANDSTONE = DOMINANTLY LOOSE GRAINS; CLEAR TO WHITE TO TRANSLUCENT GRAINS; UPPER FINE TO LOWER MEDIUM GRAINS; SME LOOSE UPPER MEDIUM GRAINS; ANGULAR TO SUBANGULAR; MOD WELL SORTED; LOW SPHERICITY; SME PRESERVED LIGHT GRAY WITH BROWNISH HUES FROM MUD IN TRAYS; ASH/SILT MATRIX; TRACE MATRIX SUPPORTED SPECIMENS; TRACE LOOSE JASPER, LIGHT GREEN BROKEN GRAINS; EXHIBITED A 60 UNIT GAS INCREASE OVER BACKGROUND. Olson Creek #2 10 TUFFACEOUS SANDSTONE/SAND/ASH = VERY LIGHT GRAY TO VERY PALE ORANGE-PINKISH GRAY (ASH HUES); CLAST SIZE MEDIUM LOWER TO FINE LOWER; SUB ANGULAR TO SUB ROUND; MODERATE DEVELOPED SPHERICITY; MODERATE TO POOR SORTING; IMPACT TEXTURE; IMMATURE - MATURE NATURE UNCONSOLIDATED TO INTERBEDDED SANDS; HETROGENEOUS BEDDING; CLEAN SAND TO INTERBEDDED IN ABUNDANY ASH/SILT MATRIX; BOTH GRAIN AND MATRIX SUPPORTED; COMPOSED OF >90% QUARTZ, SECONDARY CHERT TRACE SILICEOUS MUDSTONE; POOR TO GOOD POROSITY AND PERMEABILITY; NO OIL. ASH/SILTSTONE = OFF WHITE TO PINKISH GRAY; TUFFACEOUS SILT INTERBEDDED WITH DEVITRIFIED ASH AND LOCAL TUFFITE; POORLY INDURATED; EARTHY LUSTER; ASHY TO SILTY TEXTURE; APPEARS REWORKED AND REDEPOSITED; GRADING TO ASHY TUFFACEOUS SILTSTONE AND MINOR BEDS OF VERY FINE GRAIN TUFFACEOUS SANDSTONE; COMPOSED OF 40% ASH, 40% SILT, 20% VERY FINE SAND, CARBON FINES AND PYROCLASTIC SHARDS; NO DISCERNABLE BEDDING OR SEPARATION POINTS. CARBONACEOUS SHALE AND CLAY/COAL = BROWNISH GRAY TO PALE BROWN IN CARBON CLAY TO BLACK IN BITUMINOUS COAL; BRITTLE IN CARBON CLAY TO HARD IN COAL; EARTHY TO DISTINCT RESINOUS LUSTER; SILT TO ASHY CARBON CLAY TEXTURE TO MATTE IN COAL; SUBPLANAR FRACTURE IN CARBON CLAY TO HACKLY IN COAL; VISIBLE BLEEDING GAS IN MOST COAL FRAGMENTS; OCCURS AS THIN COAL BEDS TO THICK CARBONACEOUS CLAY AND CARBONACEOUS SHALE. TUFFACEOUS SILTSTONE = PALE BROWN TO VERY PALE ORANGE AND VARIOUS HUES OF BOTH COLORS; GRADATIONAL SILT AND VARIOUS DEGREES OF CARBON CLAY; POOR INDURATION NON TO SLIGHTLY COHESIVE SLIGHTLY ADHESIVE; EARTHY FRACTURE; SUB NODULAR TO SUB PLANAR HABIT; HYDROPHILIC EARTHY LUSTER + LIGHT CARBON APPEARANCE; ASHY TO SILTY TEXTURE; GRADATIONAL BEDS OF SILT AND CARBON CLAY/SILT; SOME MICRO LAMINAE OF BLACK CARBON SCATTERED. CONGLOMERATE SAND (THIN BEDS) = VERY LIGHT GRAY TO OFF WHITE; CLAST SIZE COARSE LOWER TO FINE UPPER; SUB ANGULAR TO SUB ROUND; MODERATE DEVELOPED SPHERICITY; POOR TO MODERATE SORTING; IMPACT TO SOME CHIP TEXTURE; SUB MATURE NATURE; UNCONSOLIDATED TO SCATTERED MODERATE CONSOLIDATED CLUSTERS; GRAIN SUPPORT TO SECONDARY MATRIX SUPPORT; TRACE EPIDOTE STAIN; ASH SCATTERED THROUGH OUT SAMPLE; COMPOSED OF PREDOMINANTLY QUARTZ, SECONDARY CHERT TRACE DARK LITHICS (VOLC?); POOR TO FAIR POROSITY AND PERMEABILITY; NSFOC. COAL/CARBONACEOUS SHALE = DOMINANT BLACK; SME DARK GRAY TO BROWN IN CARBONACEOUS SHALE SPECIMENS; MODERATELY HARD; FLAKY TO BLOCKY CUTTINGS; PLANAR TO BLOCKY FRACTURE; RESINOUS LUSTER IN CARBONACEOUS SHALE; VITREOUS LUSTER IN HIGH GRADE COAL; SOME BROWN SHALE LAMINATIONS IN COAL INDICATING THIN INTERBEDDING; ASSOCIATED WITH MULTIPLE GAS SHOWS RANGING FROM 103 TO 163 UNITS SAND/SANDSTONE/CONGLOMERATIC SANDSTONE = VERY LIGHT GRAY; CLAST SIZE COARSE UPPER TO MEDIUM LOWER; SUB ANGULAR TO SUB ROUND; SOME ANGULAR BIT IMPACTED COARSE GRAINS; MODERATE DEVELOPED SPHERICITY; MODERATE SORTING; BIMODAL WITH COARSE CONGLOMERATIC TO MEDIUM GRAIN MATRIX SAND; IMPACTED TO CHIP TEXTURE; SUB MATURE NATURE; UNCONSOLIDATED WITH SECONDARY MEDIUM GRAIN CONSOLIDATED SANDSTONE CLUSTERS; BOTH GRAIN AND MATRIX SUPPORTED; ASH MATRIX DECRESING WITH DEPTH AS WELL AS GRAIN SIZE; COMPOSED OF PREDOMINANTLY QUARTZ, SECONDARY CHERT; TRACE EPIDOTE, FELDSPAR, IGNEOUS AND CHLORITE; FAIR POROSITY; FAIR TO POOR PERMEABILITY; NO SHOW OF OIL FLUORESCENCE OR OIL CUTS. Olson Creek #2 11 SAND = VERY LIGHT GRAY; CLAST SIZE PRIMARY COARSE LOWER TO FINE LOWER, SECONDARY COARSE UPPER TO VERY COARSE AND VERY FINE GRAINS; COARSE DECREASING WITH DEPTH; SUB ANGULAR TO SUB ROUND; SCATTERED ANGULAR COARSE BIT IMPACTED GRAINS; MODERATE TO POOR SORTED IMPACT TO CHIP (COARSE GRAIN) TEXTURE; SUB MATURE NATURE; PREDOMINANTLY UNCONSOLIDATED SECONDARY CLUSTERS OF FINE GRAIN SANDSTONE; BOTH GRAIN AND ASH SUPPORT; ASH HYDROPHILIC; COMPOSED OF PREDOMINANTLY QUARTZ, SECONDARY CHERT, TRACE EPIDOTE, CHLORITE, IGNEOUS, TUFF MUSCOVITE; FAIR POROSITY AND PERMEABILITY NO SHOW OF OIL FLUORSECENCE OR CUT. DEVITRIFIED TUFF AND ASH = CONTINUED SAND ABOVE WITH LIGHT GREENISH GRAY TO VERY LIGHT GRAY DEVITRIFIED TUFF PINKISH GRAY DEVITRIFIED ASH AS MATRIX OR INTERBEDDED; GLASS SHARDS NOT DISCERNABLE DUE TO DEVITRIFICATION GRADS TO TUFF IN PARTS; POOR TO MODERATE INDURATION; SATIN TO RESINOUS TO EARTHY LUSTER; SMOOTH TO ASHY TEXTURE. Olson Creek #2 12 3.3 WELL LITHOLOGY SANDSTONE/CONGLOMERATIC SAND (150'-180') = DOM LOOSE GRAINS; CLEAR TO TRANSLUCENT GRAINS; DOM UPPER FINE TO UPPER MEDIUM GRAINED; TRACE BROKEN COARSE GRAINS; VARICOLORED GRAINS; DOM ANGULAR TO SUBANGULAR; LIGHT GREEN TO REDDISH GRAINS; MOD SORTED; TRACE ANGULAR CHERT; NO PRESERVED MATRIX; NO VISIBLE OIL INDICATORS. TUFFACEOUS SILTSTONE (180'-210') = MED TO LIGHT GRAY; VERY SOFT AND MUSHY; NO VISIBLE STRUCTURE; MASSIVE CUTTINGS; IRREGULAR FRACTURE; CLAYEY TO SILTY TEXTURE; GRADING TO TUFFACEOUS CLAYSTONE NON CALCAREOUS; VERY FINE SCATTERED CARBONACEOUS MATERIAL. SANDSTONE (180'-210') = DOMINANTLY LOOSE GRAINS; SOME PRESERVED SOFT WHITE GRAY EXAMPLES; MUSHY IN PART; LOWER FINE TO UPPER MEDIUM GRAINED; MOD SORTING; ANGULAR TO SUBANGULAR; MOD TO POOR SORTING; LOW TO MOD SPHERICITY; SOME PRESERVED SILT/CLAY MATRIX MATERIAL; SME LIGHT GREEN GRAINS. TUFFACEOUS SILTSTONE (270'-300') = TAN; LIGHT BROWN; HARD; MASSIVE CUTTINGS; IRREGULAR FRACTURE; BROWN CLAY MATRIX; VERY FINE SILT TO LOWER FINE QUARTZ GRAINS; SILTY TEXTURE; DULL LUSTER; NO VISIBLE STRUCTURE; INTER BEDDED FINE CARBONACEOUS SHALE AND CARBON FINES; GRADATIONAL AND HYDROPHILIC. SANDSTONE (300'-330') = DOMINANTLY LOOSE GRAINS; SOME OFFWHITE MUSHY PRESERVED SPECIMENS; LOWER TO UPPER FINE GRAINED; CLAY/SILTY MATRIX; MODERATE WELL SORTED; ANGULAR TO SUBANGULAR; MOD SPHERICITY; SME FINE LIGHT GREEN GRAINS; MINOR VERY FINE BLACK PARTICLES; SOME SCATTERED REDDISH TUFFACEOUS CLAYSTONE (330'-450') = VERY LIGHT GRAY; VERY SOFT TO SOFT; MALLEABLE TO SECTILE; FLEXIBLE TO SUB ELASTIC; MUSHY TO PASTY; TACKY TO SLIMY; MODERATE COHESIVE; VERY ADHESIVE; EARTHY FRACTURE TO AMORPHOUS FRACTURE; MASSIVE HABIT; EARTHY LUSTER; CLAYEY TEXTURE; MASSIVE HOMOGENEOUS TUFFACEOUS CLAY WITH MINOR TUFFACEOUIS SILT; INTERBEDDED CARBONACEOUS FINES. TUFFACEOUS CLAYSTONE (450'-540') = VERY LIGHT GRAY TO LIGHT GRAY; EVEN COLOR HUE VERY SOFT TO SOFT; MALLEABLE TO SECTILE; FLEXIBLE TO SUB ELASTIC; MUSHY TO PASTY; TACKY TO SLIMY; SLIGHT TO MODERATE COHESIVENESS; VERY ADHESIVE; EARTHY TO AMORPHOUS FRACTURE; AMORPHOUS TO MASSIVE HABIT WITH SUB NODULAR LARGE CUTTINGS FROM WELL BORE TRANSPORT; EARTHY LUSTER; CLAYEY TEXTURE; MINOR SILT INTERBEDDED WITH PYRO CLASTIC RELIC SHARDS IN MASS. TUFFACEOUS CLAYSTONE (540'-600') = VERY LIGHT GRAY TO LIGHT MEDIUM GRAY AND SLIGHT VARIOUS HUES OF BOTH; VERY SOFT TO SOFT; MALLEABLE TO SECTILE; FLEXIBLE TO SUB ELASTIC; MUSHY TO PASTY; TACKY TO SLIMY; SLIGHTLY COHESIVE TO VERY ADHESIVE; EARTHY TO AMORPHOUS FRACTURE; MASSIVE TO SUB NODULAR HABIT FROM WELL BORE EROSIONAL TRANSPORT; VISIBLE PYRO CLASTIC RELIC SHARDS INTERBEDDED; BECOMING SLITY IN PARTS; OVERALL VERY HOMOGENEOUS COMPOSED OF 90% CLAY, 10% SILT; NO DISCERNABLE BEDDING, VISIBLE FEATURES, FRACTURES OR SEPARATION POINTS TUFFACEOUS CLAYSTONE (600'-660') = DOM PRESERVED AS CLAY; LIGHT GRAY TO LIGHT MEDIUM GRAY; MUSHY; SOFT; MASSIVE TO SLI NODULAR HABIT FROM TRANSPORT; Olson Creek #2 13 EARTHY TO IRREGULAR FRACTURE; SILTY IN PART; FINE LOOSE SILTY IN TRAYS AFTER COMPLETE WASHING; GRADING TO TUFFACEOUS SILTSTONE. TUFFACEOUS CLAYSTONE( 660'-720') = LIGHT GRAY; PRESEVED AS AMORPHOUS CLAY; MUSHY TO PASTY; SOFT; COHESIVE TO VERY ADHESIVE; MASSIVE TO SLIGHTLY NODULAR CUTTINGS; IRREGULAR FRACTURE; DULL EARTHY LUSTER; VERY CLAYEY TEXTURE; ABUNDANT LOOSE SILT TO VERY FINE QUARTZ GRAINS IN HEAVILY WASHED SAMPLES; LOOSE VERY FINE CARBONACEOUS MATERIAL; SILTY IN PART; GRADING TO TUFFACEOUS SILTSTONE. SAND (720'-750') = PRESERVED AS LOOSE GRAINS; VERY FINE TO FINE GRAINED; MOD WELL SORTED; ANGULAR TO SUBANG; MOD SPHERICITY; NO MATRIX PRESERVED; SOME LOOSE LIGHT GREEN GRAINS; SME VERY FINE CARBONACEOUS MATERIAL; NO OIL INDICATORS. TUFFACEOUS CLAYSTONE (750'-780') = LIGHT GRAY; SOFT; MUSHY TO PASTY; PRESERVED AS AMORPHOUS LIGHT GRAY CLAY; DULL EARTHY LUSTER; CLAYEY TEXTURE VERY ADHESIVE; ABUNDANT LOOSE SILT SIZE QUARTZ IN WASHED TRAYS; SCATTERED BLACK VERY FINE CARBONACEOUS MATERIAL. CARBONACEOUS SHALE (780'-810') = DARK GRAY; SME DARK BROWNISH HUES; HARD; SLI PLATY CUTTINGS; PLANAR TO SLI BLOCKY FRACTURE; SMOOTH TEXTURE; DULL EARTHY LUSTER; INTERBEDDED WITH TUFFACEOUS CLAYSTONE. SAND (810'-840') = LOOSE QUARTZ; CLEAR TO TRANSLUCENT TO SOME OPAQUE GRAINS; VERY FINE TO FINE GRAINED; ANGULAR TO SUBANGULAR; MOD WELL SORTED; TRACE LIGHT GREEN TO REDDISH GRAINS; TRACE LIGHT GRAY CHERT; LOW SPHERICITY; NO MATRIX PRESERVED; VERY FINE CARBONACEOUS MATERIAL; SLIGHT GAS INCREASE OVER INTERVAL; NO OIL INDICATORS. TUFFACEOUS CLAYSTONE (840'-870') = LIGHT GRAY; SOFT; MUSHY TO PASTY; MASSIVE CUTTINGS; IRREGULAR FRACTURE; DULL EARTHY LUSTER; CLAYEY TEXTURE; SILTY TO SANDY IN PART; INTERBEDDED WITH THIN CARBONACEOUS SHALE AND SANDSTONE. SAND (900'-930') = ABUNDANT LOOSE GRAINS; NO PRESERVED SPECIMENS; DOM CLEAR TO TRANSLUCENT GRAINS; SOME WHITE TO LIGHT GREEN TO REDDISH GRAINS; LOWER FINE TO UPPER FINE GRAINED; MOD WELL SORTED; ANGULAR TO SUBANGULAR; LOW SPHERICITY; NO MATRIX PRESERVED; TRACE LOOSE COARSE MICA; NO HYDROCARBON INDICATORS. TUFFACEOUS CLAYSTONE (930'-990') = LIGHT GRAY PRESERVED SPECIMENS; DOMINANTLY LIGHT GRAY MUSHY TO PASTY CLAY; SOFT PRESERVED SPECIMENS; MASSIVE CUTTINGS TO SLI NODULAR CUTTINGS FROM TRANSPORT; DULL EARTHY LUSTER; CLAYEY TEXTURE; SILTY TO SANDY; ABUNDANT LOOSE SILT TO VERY FINE QUARTZ SAND; LOOSE VERY FINE CARBONACEOUS MATERIAL. CARBONACEOUS SHALE (1020'-1050') = DARK BROWN TO DARK GRAY; MOD HARD; PLATY CUTTINGS; PLANAR TO BLOCKY FRACTURE; DULL EARTHY LUSTER; SMOOTH TO ROUGH TEXTURE; NO VISIBLE STRUCTURE; THINLY INTERBEDDED WITH TUFFACEOUS CLAYSTONE. COAL/CARBONACEOUS SHALE (1050'-1110') = DARK GRAY; DARK BROWN; SME TANISH HUES DULL EARTHY TO SLI RESINOUS LUSTER; HARD IN DARK GRAY SPECIMENS; BECOMING SOFT IN BROWNISH SPECIMENS; SLI PLATY CUTTINGS; IRREGULAR TO PLANAR FRACTURE; SOME THIN LAMINATIONS; SOME THIN MICRO PYRITE LAMINATIONS; SME BLEEDING GAS IN SAMPLES; DARK BROWN DOM CARB SHALE; LOW GRADE COAL; MINOR GAS INCREASES OVER THIS CARBONACEOUS INTERVAL. Olson Creek #2 14 TUFFACEOUS CLAYSTONE(1110'-1140') = PRESERVED AS SOFT, MUSHY LIGHT GRAY CLAY; SMOOTH TO CLAYEY TEXTURE ON PRESERVED SPECIMENS; DULL EARTHY LUSTER; MASSIVE CUTTINGS; IRREGULAR FRACTURE; ABUNDANT LOOSE SILT IN SAMPLE TRAYS; INTERBEDDED WITH DARK GRAY CARBONACEOUS SHALE. TUFFACEOUS CLAYSTONE (1140'-11179') = LIGHT GRAY; SOFT; MUSHY; VERY ADHESIVE; NON CALCAREOUS; MASSIVE TO SLI NODULAR CUTTINGS; IRREGULAR FRACTURE; DULL EARTHY LUSTER; SMOOTH TO SILTY TEXTURE; SILTY IN PART; GRADING TO TUFFACEOUS SILSTONE; LOOSE SILT IN SAMPLE TRAYS. SAND (1200'-1230') = ABUNDANT LOOSE GRAINS IN SAMPLE TRAYS; DOM CLEAR TO TRANSLUCENT GRAINS; MOD WELL SORTED; LOWER FINE TO LOWER MEDIUM GRAINED; LOW SPHERICITY; ANGULAR TO SUBANGULAR; TRACE VARICOLORED LOOSE GRAINS; NO PRESERVED MATRIX; NO HYDROCARBON INDICATORS. TUFFACEOUS CLAYSTONE (1230'-1305') = VERY LIGHT GRAY TO PINKISH GRAY AND VERY SUBTLE DIFFERENCE IN HUES; VERY SOFT; HYDROPHILIC; CLUSTERED TO CLOTTED; NON TO VERY SLIGHT COHESIVENESS; MODERATE ADHESIVE; AMORPHOUS FRACTURE; MASSIVE HABIT; EARTHY LUSTER; COLLIDAL TO ASHY TEXTURE; MASSIVE GRADATIONAL TUFFACEOUS CLAY WITH INTERBEDDED FINE TO MEDIUM GRAINED SAND; MINOR THIN CARBON SHALE LAMINAE; TRACE TUFFITE FRAGMENTS. CARBONACEOUS SHALE/COAL (1305'-1310') = DUSKY BROWN MOTTLED BLACK; MINOR LIGHT BROWN; FIRM; EARTHY LUSTER; MOTTLED TO STRIATED TEXTURE; SUB PLANAR FRACTURE ALONG SHALE PARTINGS; INTERBEDDED DETRITAL MATERIAL NEAR CONTACT; DISTINCT DIFFERING CARBON GRADES; LOW GRADE; VISIBLE BLEEDING GAS FROM LARGE CUTTINGS TUFFACEOUS CLAYSTONE (1310'-1390') = MEDIUM LIGHT GRAY TO LIGHT BROWNISH GRAY VERY SOFT; MALLEABLE TO SECTILE; MUSHY TO PASTY; TACKY TO SLIMY; NON TO SLIGHT COHESIVE; MODERATE TO VERY ADHESIVE; AMORPHOUS FRACTURE AND HABIT; EARTHY LUSTER; CLAYEY TO ASHY TEXTURE; MASSIVE HOMOGENEOUS CLAYS COMPOSED OF >90% CLAY; CARBON SHALE @ 1345'-1355' COAL/CARBON SHALE (1390'-1405') = BLACK MOTTLED LIGHT BROWN TO MICRO LAMINAE OF GRAYISH BROWN; FIRM; STRIATED TO MOTTLED TEXTURES; SUB PLANAR FRACTURE ALONG SHALE PARTINGS TO BLOCKY IN TRUE COAL; DISTINCT THIN LAMINAE OF DIFFERING CARBONS; VISIBLE BLEEDING GAS IN LARGE CUTTINGS; GRADING TO TUFFACEOUS CLAY. TUFFACEOUS CLAYSTONE (1405'-1500') = VERY LIGHT GRAY TO LIGHT GRAY; VERY SOFT SLIGHTLY SECTILE; MUSHY TO PASTY; TACKY TO SLIMY; NON TO SLIGHTLY COHESIVE; MODERATE TO VERY ADHESIVE; AMORPHOUS FRACTURE AND HABIT; HYDROPHILIC; EARTHY LUSTER; CLAYEY TO COLLOIDAL TEXTURES; MASSIVE HOMOGENEOUS TUFFACEOUS CLAY; COMPOSED OF >90% CLAY, PYRO CLASTIC RELIC SHARDS AND TRACE DETRITAL MATERIAL TRACE THIN LAMINAE OF POOR INDURATED CARBONACEOUS TUFFACEOUS SILTSTONE NOTED AT 1470'. TUFFACEOUS CLAYSTONE (1500'-1575') = VERY LIGHT GRAY TO LIGHT GRAY; VERY SOFT SLIGHTLY SECTILE; MUSHY TO PASTY; TACKY TO SLIMY; NON TO SLIGHTLY COHESIVE; MODERATE TO VERY ADHESIVE; AMORPHOUS FRACTURE AND HABIT; HYDROPHILIC; EARTHY LUSTER; CLAYEY TO COLLOIDAL TEXTURES; MASSIVE HOMOGENEOUS TUFFACEOUS CLAY; COMPOSED OF >90% CLAY, PYRO CLASTIC RELIC SHARDS AND TRACE DETRITAL MATERIAL Olson Creek #2 15 CARBONACEOUS SHALE/COAL (1575'-1605') = BROWNISH BLACK TO BROWNISH GRAY TO DUSKY BROWN AND VARIOUS HUES OF ALL; FIRM TO HARD; EARTHY LUSTER; MATTE TO STRIATED TO MOTTLED TEXTURE; BLOCKY TO SUB PLANAR FRACTURE; DISTINCT LAMINAE OF DIFFERENT CARBON GRADES; VISIBLE BLEEDING GAS. SAND (1605' MINOR INTERBEDDING TO 1660' INTERBEDDED) = LIGHT GRAY TO MEDIUM GRAY CLAST SIZE COARSE LOWER TO FINE LOWER; SUB ROUND TO ROUNDED; WELL DEVELOPED SPHERICITY; POLISH TEXTURE; IMMATURE NATURE; DOMINENT CLAY SUPPORT TO INTBD IN CLAY; PORE FILLING MATRIX LOOSELY ATTACHED; HYDROPHILIC MATRIX; COMPOSED DOMINANT QUARTZ, SECONDARY CHERT, 20-30% DARK GRAY TO GRAY SILICEOUS SILTSTONE, ARGILLITE AND VOLCANIC FRAGMENTS; POOR POROSITY AND PERMEABILITY; NO OIL INDICATORS TUFFACEOUS CLAYSTONE/CARBONACEOUS SHALE (1660'-1770') = GRADATIONAL BEDS OF MASSIVE TUFFACEOUS CLAY AND THIN TO THICK BEDS OF VERY CARBONACEOUS SHALE AND VERY THIN LOW GRADE COAL = GRAYISH BLACK MOTTLED DUSKY BROWN TO GRAYISH BROWN; FIRM; EARTHY LUSTER; MATTE TO STRIATED TEXTURES; BLOCKY TO SUB BLOCKY FRACTURE; VISIBLE DIFFERING CARBON GRADE IN MICRO LAMINATIONS; SLIGHT VISIBLE BLEEDING GAS; GRADING TO HYDROPHILIC CLAYS WITH MINOR SILT. TUFFACEOUS CLAYSTONE (1770'-1830') = VERY LIGHT GRAY TO LIGHT GRAY; SOFT PRESERVED SPECIMENS; DOM PRESERVED AS MASSIVE, HOMOGENOUS CLAY; DULL EARTHY LUSTER; CLAYEY TEXTURE; IRREG FRACTURE; MUSHY TO PASTY; SLI COHESIVE; MOD TO VERY ADHESIVE; INTERBEDDED W/ THIN CARBONACEOUS SHALE. TUFFACEOUS CLAYSTONE (1830'-1860') = LIGHT GRAY TO VERY LIGHT GRAY; PRESERVED AS MASSIVE, HOMOGENOUS CLAY; OCC SLI NODULAR FROM TRANSPORT; IRREGULAR FRACTURE; NON CALCAREOUS; CLAYEY TEXTURE; MUSHY; SOME LOOSE VERY FINE CARBONACEOUS MATERIAL; SOME LOOSE SILT TO LOWER FINE QUARTZ IN SAMPLE TRAYS; INTERBEDDED WITH THIN CARBON CARBONACEOUS SHALE (1860'-1890') = DARK GRAY TO BLACK; MOD HARD; THIN PLATY CUTTINGS; PLANAR TO BLOCKY FRACTURE; SLIGHTLY RESINOUS LUSTER TO DULL EARTHY LUSTER; ROUGH TEXTURE; TRACE DARK BROWNISH SPECIMENS; NON CALCAREOUS; THINLY INTERBEDDED IN TUFFACEOUS CLAYSTONE. TUFFACEOUS CLAYSTONE(1890'-1920') = LIGHT GRAY TO MEDIUM LIGHT GRAY PRESERVED SPECIMENS; DOM MASSIVE SOFT, HOMOGENOUS CLAY; VERY ADHESIVE; DULL EARTHY LUSTER; CLAYEY TEXTURE; INCREASE IN SILT/QUARTZ SAND IN SAMPLE TRAYS; BECOMING SILTY TO SANDY; W/ DARK GRAY CARBONACEOUS SHALE. TUFFACEOUS CLAYSTONE(1920'-2025') = PRESERVED AS MASSIVE LIGHT GRAY TO LIGHT MEDIUM GRAY CLAY; SOFT; DULL EARTHY LUSTER ON RARE PRESERVED SPECIMENS; CLAYEY TEXTURE; OCC SILTY; NON CALCAREOUS; LOOSE VERY FINE CARBONACEOUS MATERIAL; TRACE MINOR LOOSE SILT TO VERY FINE QUARTZ IN SAMPLE TRAYS. SAND (2025'-2080') = VERY LIGHT GRAY; CLAST SIZE MEDIUM UPPER TO FINE UPPER; SUB ROUND TO SUB ANGULAR; MODERATE DEVELOPED SPHERICITY; TRACE PROLATED GRAINS; MODERATE TO WELL SORTED WITH UNIFORM DISTRIBUTION; IMPACTED TO PITTED TEXTURE; MATURE NATURE; UNCONSOLIDATED; NO VISIBLE MATRIX; ARENACEOUS; COMPOSED OF >90% QUARTZ, SECONDARY CHERT AND TRACE GRAY LITHICS; GOOD POROSITY AND PERMEABILITY; NO OIL INDICATORS. Olson Creek #2 16 TUFFACEOUS CLAYSTONE (2080'-2190') = MEDIUM LIGHT GRAY TO LIGHT GRAY; SOFT; MUSHY TO PASTY; EARTHY TO SUB PDC FRACTURE WITH COMPRESSIVE DISPLACEMENT CUTTINGS FAILURE AND DEFORMATION WITH DISTINCT CRENULATIONS OF PDC BIT CUTTERS EARTHY LUSTER; CLAYEY TO ASHY TEXTURE; GRADTIONAL HARDNESS WITH INTERBEDDED SILTS AND SAND; INCREASED SILT AND FINE GRAINED SAND CONTENT WITH DEPTH. TUFFACEOUS SILTSTONE (2190'-2220') = VERY LIGHT GRAY; POOR INDURATION; MUSHY; LIGHTLY COHESIVE, MODERATE ADHESIVE; EARTHY FRACTURE; SUB NODULAR HABIT FROM WELL BORE EROSIONAL TRANSPORT; MODERATE TO BRIGHT EARTHY LUSTER; SILTY TO CLAYEY TEXTURE; MASSIVE HOMOGENEOUS BEDS OF TUFFACEOUS SILT WITH DECREASED CLAY CONTENT WITH DEPTH; COMPOSED OF 70% SILT, 30% CLAY AND VARIOUS DETRITAL. TUFFACEOUS SILTSTONE (2220'-2300') = MEDIUM LIGHT GRAY AND SUBTLE DIFFERENCES IN COLOR HUES; POOR INDURATION; OVERALL MUSHY; SLIGHTLY COHESIVE; SLIGHTLY TO MODERATE ADHESIVENESS WITH INCREASED CLAY CONTENT; EARTHY FRACTURE; SUB NODULAR HABIT FROM WELL BORE EROSIONAL TRANSPORT; SOME PDC GROOVED CUTTINGS FROM FIRMER CUTTINGS; MODERATE EARTHY LUSTER; SILTY TO CLAYEY TEXTURE; MASSIVE HOMOGENEOUS TUFFACEOUS SILTSTONE; COMPOSED OF 70% SILT, 20% CLAY, 10% VERY FINE GRAIN SAND INTERBEDDED AND VARIOUS DETRITAL MATERIAL. TUFFACEOUS SILTSTONE (2300'-2370') = MEDIUM LIGHT GRAY AND SUBTLE DIFFERENCES IN COLOR HUES; POOR INDURATION; OVERALL MUSHY; SLIGHTLY COHESIVE; SLIGHTLY TO MODERATE ADHESIVENESS WITH INCREASED CLAY CONTENT; EARTHY FRACTURE; SUB NODULAR HABIT FROM WELL BORE EROSIONAL TRANSPORT; SOME PDC GROOVED CUTTINGS FROM FIRMER CUTTINGS; MODERATE EARTHY LUSTER; SILTY TO CLAYEY TEXTURE; MASSIVE HOMOGENEOUS TUFFACEOUS SILTSTONE; COMPOSED OF 70% SILT, 20% CLAY, 10% VERY FINE GRAIN SAND INTERBEDDED. THIN BEDS OF PLATY VERY CARBONACEOUS SHALE ARE SCATTERED THROUGHOUT THIS SECTION. TUFFACEOUS SILTSTONE (2370'-2460') = MEDIUM LIGHT GRAY AND SUBTLE DIFFERENCES IN COLOR HUES; POOR INDURATION; OVERALL MUSHY; SLIGHTLY COHESIVE; SLIGHTLY TO MODERATE ADHESIVENESS WITH INCREASED CLAY CONTENT; EARTHY FRACTURE; SUB NODULAR HABIT FROM WELL BORE EROSIONAL TRANSPORT; SOME PDC GROOVED CUTTINGS FROM FIRMER CUTTINGS; MODERATE EARTHY LUSTER; SILTY TO CLAYEY TEXTURE; MASSIVE HOMOGENEOUS TUFFACEOUS SILTSTONE; MICRO LAMINATED CARBON CLAY WITH SOME PLANAR ORIENTATION @ 2400'; INCREASED VERY FINE GRAIN SAND INTERBEDDED @ 2460' TUFFACEOUS SILTSTONE (2460'-2590') = MEDIUM LIGHT GRAY; POOR INDURATION; OVERALL MUSHY; SLIGHT COHESIVENESS; SLIGHT TO MODERATE ADHESIVENESS; EARTHY FRACTURE; SUBNODULAR TO PDC BIT HABIT THROUGH METAMORPHISM CAUSED BY COMPRESSIVE DISPLACEMENT OF MATRIX FAILURE AND PLASTIC DEFORMATION; CUTTING IN LONG AXIS PROFILE WITH PARALLEL CRENULATIONS AND POLISHED SURFACES ON THE OPPOSITE SIDE; TIGHTLY COMPACTED FLUTED PARALLEL HIGH RELIEF CRENULATIONS ON THE CONCAVE INNER SURFACE; SILTY TO CLAYEY TEXTURE; MASSIVE HOMOGENEOUS TUFFACEOUS SILT WITH LOCAL GRADATIONS OF TUFFACEOUS CLAY; BECOMING SLIGHTY INTERBEDDED WITH FINE GRAIN SAND. SAND/SANDSTONE (INTERBEDDED) (2590-2615) = VERY LIGHT GRAY TO LIGHT GRAY; CLAST FROM FINE UPPER TO VERY FINE LOWER; SUB ANGUGLAR TO SUB ROUND; POOR SORTING; IMPACT TEXTURE; IMMATURE NATURE; VERY WEAK SILICIOUS CEMENT; DOMINANT GRAIN SUPPORT; SILT/ASH/CLAY MATRIX LOOSELY ATTACHED AND PORE FILLING; DETRITALISH; Olson Creek #2 17 COMPOSED OF QUARTZ, SECONDARY CHERT, 20-30% SILICIOUS MUDSTONE, ARGILLITE W/ VARIOUS LITHIC DARK FRAGMENTS; SLIGHTLY CALCARIOUS; POOR POROSITY AND POOR PERMEABILITY; NO OIL INDICATORS. TUFFACEOUS SILTSTONE(2640'-2670') = MEDIUM LIGHT GRAY; SOFT TO MUSHY; DOMINANTLY ADHESIVE CLAY; MASSIVE HOMOGENEOUS SILT; DULL EARTHY LUSTER ON PRESERVED SPECIMENS; CLAYEY TEXTURE; VARIABLE AMOUNTS OF SILT; ABUNDANT LOOSE SILT IN SAMPLE TRAYS; SME VERY FINE CARBONACEOUS MATERIAL; INTERBEDDED WITH THIN POOR GRADE COALS. TUFFACEOUS SILTSTONE (2670'-2730') = LIGHT GRAY TO MEDIUM LIGHT GRAY; MASSIVE TO SLI PLATY TO SLIGHT NODULAR CUTTINGS FROM TRANSPORT; SOFT TO MUSHY; IRREGULAR TO EARTHY FRACTURE; DOMINANT PRESERVED AS HOMOGENEOUS CLAY; DULL EARTHY LUSTER; SMOOTH TO CLAYEY TEXTURE; VARIABLE AMOUNTS OF SILT; GRADING TO TUFFACEOUS CLAYSTONE; VERY FINE CARBONACEOUS MATERIAL; LOOSE SILT IN SAMPLE TRAYS; INTERBEDDED WITH THIN POOR GRADE COALS. CARBONACEOUS SHALE/COAL (2730'-2760') = DARK GRAY; TRACE DARK BROWNISH GRAY; MOD HARD; SLI PLATY CUTTINGS; IRREGULAR TO PLANAR FRACTURE; DULL EARTHY TO SLI RESINOUS LUSTER; SMOOTH TEXTURE; OCC SOME THIN LAMINATIONS; ASSOCIATED WITH SLIGHT GAS INCREASES; THINLY INTERBEDDED IN TUFFACEOUS SILTSTONE. TUFFACEOUS SILTSTONE (2760'-2790') = LIGHT GRAY TO LIGHT MEDIUM GRAY; SMOOTH TEXTURE; SOFT; DULL EARTHY LUSTER; PRESERVED DOM AS CLAY; MOD ADHESIVE; NON CALCAREOUS; VARIABLE AMOUNTS OF SILTY AND VERY FINE QUARTZ IN A CLAY MATRIX; INTERBEDDED WITH THIN DARK GRAY CARBONACEOUS SHALE/COAL. SAND/SANDSTONE(2790'-2850') = DOMINANT LOOSE GRAINS; POORLY REPRESENTED IN SAMPLES; LOWER FINE TO UPPER FINE GRAINED; ANGULAR TO SUBANGULAR; LOW TO MOD SPHERICITY; NO MATRIX PRESERVED; TRACE LIGHT GREEN GRAINS; NO HYDROCARBON INDICATORS. CARBONACEOUS SHALE/COAL (2850'-2880') = DARK GRAY; MOD HARD; SLI PLATY CUTTINGS; BLOCKY TO PLANAR FRACTURE; SMOOTH TO ROUGH TEXTURE; DULL EARTHY TO SLIGHTLY RESINOUS LUSTER; THINLY BEDDED IN TUFFACEOUS SILTSTONE AND SANDSTONE. TUFFACEOUS SILTSTONE (2880'-2910') = VERY LIGHT TO LIGHT GRAY PRESERVED SPECIMENS; SOFT; MUSHY IN PART; SLI INCREASE IN FIRMNESS; NON CALCAREOUS; DULL EARTHY LUSTER; CLAYEY TEXTURE; VARIABLE AMOUNTS OF SILT IN CLAY MATRIX; LOOSE VERY FINE CARBONACEOUS MATERIAL. TUFFACEOUS SANDSTONE(2940'-3000') = POORLY PRESERVED; TRACE LIGHT WHITE GRAY MUSHY SPECIMENS; SOFT; DOMINANT LOOSE CLEAR TO TRANSLUCENT QUARTZ; LOWER FINE TO UPPER FINE GRAINED; MODERATE TO WELL SORTED; ANGULAR TO SUBANGULAR; LOW TO MOD SPHERICITY; ASH/CLAY MATRIX; TRACE VERY FINE SCATTERED CARBONACEOUS MATERIAL; NO HYDROCARBON INDICATORS. TUFFACEOUS SILTSTONE(3000'-3060') = LIGHT GRAY PRESERVED SPECIMENS; SOFT TO MUSHY; SLIGHTLY PLATY TO SLI NODULAR CUTTINGS FROM TRANSPORT; IRREGULAR FRACTURE; DULL EARTHY LUSTER; SMOOTH TO CLAYEY TEXTURE; SME THIN ASH LAMINATIONS MINOR LOOSE SILT AND SAND IN SAMPLE TRAY TRACE CARBONACEOUS MATERIAL. Olson Creek #2 18 CARBONACEOUS SHALE/COAL (3060'-3090') = DARK GRAY; MOD HARD; PLATY TO FLAKY CUTTINGS; PLANAR FRACTURE; SMOOTH TO ROUGH TEXTURE; DULL TO SLI RESINOUS LUSTER; THINLY BEDDED IN TUFFACEOUS SILTSTONE. SAND/SANDSTONE (3100'-3150') = DOMINANT LOOSE QUARTZ GRAINS; ABUNDANT TRANSLUCENT TO CLEAR GRAINS; LOWER FINE TO UPPER FINE GRAINED; BECOMING LOWER MEDIUM GRAINED WITH DEPTH; DOMINANT ANGULAR TO SUBANGULAR; LOW TO MOD SPHERICITY; TRACE MUSHY LIGHT GRAY CLAY MATRIX; TRACE BROKEN CHERT GRAINS; SOME LOOSE VARICOLORED GRAINS FROM LIGHT GREEN TO ORANGE TO REDDISH GRAINS; TRACE LOOSE LITHIC FRAGMENTS; ASSOCIATED WITH MINOR GAS INCREASES; NO FLUOR OR CUT. TUFFACEOUS SILTSTONE (3150'-3180') = LIGHT GRAY; VERY SOFT; MUSHY; INCREASED FIRMNESS; EARTHY TO MASSIVE FRACTURE; MASSIVE TO SLI PLATY TO SLI NODULAR CUTTINGS FROM TRANSPORT; NON CALCARIOUS; CLAYEY TO SILTY TEXTURE; SANDY IN PART WITH LOOSE VERY FINE QUARTZ SAND; SLIGHT COHESIVE; MODERATELY ADHESIVE; TRACE LOOSE ASH IN SAMPLES; INTERBEDDED WITH THIN LOW GRADE COAL/CARBONACEOUS SHALE. CARBONACEOUS SHALE/COAL (3180'-3210') = DARK GRAY; TRACE DARK BROWNISH GRAY; MOD HARD; PLATY TO SLI FLAKY CUTTINGS; IRREGULAR TO BLOCKY CUTTINGS; LOW GRADE COAL; DULL TO SLIGHTLY RESINOUS LUSTER IN MORE COALEY SPECIMENS; SME VISIBLE LAMINATIONS; ASSOCIATED WITH MINOR GAS INCREASES. TUFFACEOUS SILTSTONE (3210'-3325') = LIGHT GRAY WITH VARIOUS HUES; SOFT; WEAK SECTILENESS IN PARTS WITH INCREASE CLAY; SLIGHTLY COHESIVE; SLIGHTLY ADHESIVE; EARTHY FRACTURE; SUB NODULAR HABIT FROM WELL BORE EROSIONAL TRANSPORT; EARTHY LUSTER; SILTY TO ASHY TEXTURE; BECOMING SANDY IN PARTS (INTERBEDDED) VERY FINE GRAIN; GRADATIONAL SILTS COMPOSED OF 80% SILT, 20% VERY FINE GRAIN SAND, PYRO CLASTIC RELIC SHARDS, TRACE DEVITRIFIED ASH AND CARBON FINES; DECREASE IN TUFFACEOUS SAND INTERBEDS @ 3300' AND INCREASE IN ASH CONTENT; SMALL COAL AND CARBON SHALE BED @ 3330'. CARBONACEOUS SHALE/COAL (3325'-3350') = BLACK TO GRAYISH BLACK; BRITTLE CARBON SHALE TO FIRM BLOCKY COAL; DOMINANT PLANAR FRACTURE ALONG SHALE PARTINGS IN CARBON SHALE TO BLOCKY FRACTURE IN LOW NONE TO VERY SLIGHT VISIBLE BLEEDING GAS BECOMING MICRO LAYERED AND MICRO LAMINATED WITH TUFFACEOUS SILTSTONE. TUFFACEOUS SILTSTONE (3350'-3435') = LIGHT GRAY; SOFT; SLIGHTLY COHESIVE; SLIGHTLY ADHESIVE; HYDROPHILIC SUB NODULAR HABIT FROM WELL BORE EROSIONAL TRANSPORT; SILTY TO ASHY TEXTURE; COMPOSED OF 80% SILT, 20% VERY FINE SAND PYRO CLASTIC RELIC SHARDS, DEVITRIFIED ASH AND CARBON FINES; VERY THIN TO THICK CARBONACEOUS SHALES BEDS SCATTERED THROUGHOUT THE SECTION; NO VISIBLE BLEEDING OF GAS; LOW GRADE COAL TO CARBON SHALE; DISTINCT PLANAR FRACTURE OF CARBON SHALE COAL/CARBONACEOUS SHALE (3435'-3505') = BLACK MOTTLED BROWNISH BLACK; PARALLEL LAMINAR PATTERNS OF LIGHTER AND DARKER CARBON LAYERS; BRITTLE IN CARBON SHALE TO FIRM IN LOW GRADE COAL; EARTHY TO SUB RESINOUS LUSTER; PLANAR FRACTURE IN CARBON SHALE TO HACKLY IN COAL; PDC GROUND UP CUTTINGS; TRACE VISIBLE BLEEDS OF GAS FROM COAL ONLY; GRADING TO ASHY TUFFACEOUS SILTSTONE. TUFFACEOUS SILTSTONE/CARBONACEOUS SHALE (3505'-3570') = LIGHT GRAY TO PINKISH GRAY (ASH); VERY POOR TO POORLY INDURATED; SLIGHTLY SECTILE WITH CLAY CONTENT ELEVATED; MUSHY, SLIMY; SLIGHTLY COHESIVE; SLIGHT TO MODERATE ADHESIVE; EARTHY FRACTURE; SUB NODULAR HABIT FROM WELL BORE EROSIONAL TRANSPORT; EARTHY Olson Creek #2 19 LUSTER; SILTY TO ASHY TEXTURE; INCREASE IN ASH CONTENT @ 3510'; COMPOSED OF 70% SILT, 20% VERY FINE GRAIN SAND, PYRO CLASTIC RELIC SHARDS AND CARBON FINES; GRADING TO SILTY DEVITRIFIED ASH INTERBEDDED OR AS THIN BEDS; THIN LAMINAE OF CARBON SHALE. TUFFACEOUS SILTSTONE (3570'-3660') = LIGHT GRAY; VERY POOR TO POORLY INDURATED; MUSHY TO SOME PASTY; SLIMY; NON TO SLIGHTLY COHESIVE; MODERATE ADHESIVE WITH SLIGHT INCREASE IN CLAY CONTENT; EARTHY FRACTURE; AMORPHOUS IN PART TO GENERAL SUBNODULAR HABIT FROM WELL BORE EROSIONAL TRANSPORT; EARTHY LUSTER; SILTY TO ASHY TEXTURE; ASHY IN PARTS; GRADATIONAL CLAYS INTERBEDDED; COMPOSED OF 80% SILT, 20% CLAY AND CARBON FINES; CONTINUED MICRO LAMINATION OF CARBON SHALE AND INTERBEDDED DEVITRIFIED ASH; THIN BEDS OF CARBONACEOUS SHALE AND VERY LOW GRADE COAL. TUFFACEOUS SILTSTONE (3660'-3700') = LIGHT GRAY TO PINKISH GRAY (ASH); VERY POOR TO POORLY INDURATEDL MUSHY; NON TO SLIGHTLY COHESIVE; HYDROPHILIC; SLIGHT TO MODERATE ADHESIVE WITH INCREASED CLAY EARTHY FRACTURE; SUB NODULAR HABIT FROM WELL BORE TRANSPORT EROSION; EARTHY LUSTER; SILTY TO ASHY TEXTURE; VERY FINE GRAIN SAND INTERBEDDED; TRACE CARBONACEOUS FINES AND OVERALL ASHY. TUFFACEOUS SILTSTONE (3700'-3780') = LIGHT GRAY TO PINKISH GRAY (ASH HUE); VERY POOR TO POORLY INDURATED; SLIGHTLY SECTILE IN INCREASED CLAY GRADATIONS; MODERATE ADHESIVE; MUSHY TO PASTY SOME CLUSTERED TO CLOTTED; AMORPHOUS TO EARTHY FRACTURE; AMORPHOUS TO SUB NODULAR HABIT FROM WELL BORE EROSIONAL TRANSPORT; EARTHY LUSTER; SILTY TO ASHY TO CLAYEY TEXTURES; MASSIVE GRADATIONAL TUFFACEOUS SILT WITH THIN BEDS OF CARBONACEOUS SHALE AND TUFFACEOUS CLAY. TUFFACEOUS SILTSTONE (3780'-3870') = LIGHT GRAY TO VERY LIGHT GRAY; VERY POOR TO POOR INDURATION; MUSHY TO PASTY SOME CLUSTERED TO CLOTTED; AMORPHOUS TO SUB EARTHY FRACTURE; AMORPHOUS TO SUB NODULAR HABIT FROM WELL BORE EROSIONAL TRANSPORT; EARTHY LUSTER; SILTY TO ASHY TO CLAYEY TEXTURES; MASSIVE GRADATIONAL TUFFACEOUS SILT WITH MINOR ASH AND CLAY; THIN LIGNITIC COALS AT 3832' AND 3870' COAL/CARBONACEOUS SHALE (3870'-3900') = BLACK MOTTLED BROWNISH BLACK; FIRM TO SOME HARD; EARTHY MOTTLED RESINOUS LUSTERS IN CARBON SHALE AND COAL; MATTE TEXTURE; BLOCKY TO HACKLY FRACTURES; DISTINCT VISIBLE LAMINAE OF DIFFERING CARBON GRADES; VISIBLE BLEEDING GAS; COALS BECOMING MORE "CHARGED" WITH DEPTH TUFFACEOUS SILTSTONE (3900'-3960') = LIGHT GRAY TO PINKISH GRAY TO VERY PALE ORANGE (ASH); POORLY INDURATED; MUSHY TO SLIMY; SLIGHTLY COHESIVE; MODERATE ADHESIVE; EARTHY FRACTURE; SUB NODULAR HABIT FROM WELL BORE EROSIONAL TRANSPORT; EARTHY LUSTER; SILTY TO ASHY TO CLAYEY TEXTURE; MASSIVE GRADATIONAL BEDS OF TUFFACEOUS SILT, THIN LAMINAE AND BLEBS OF DEVITRIFIED ASH AND THICK COAL WITH VERY CARBONACEOUS SHALE (3915') TUFFACEOUS SILTSTONE (3960'-4020') = LIGHT GRAY TO PINKISH GRAY; VERY SOFT; LUMPY TO CLUMPY; CLUSTERED TO CLOTTED; SLIGHTLY MUSHY IN PARTS; NON TO VERY SLIGHT COHESIVE; SLIGHT TO MODERATE ADHESIVE; AMORPHOUS FRACTURE AND HABIT; DULL EARTHY LUSTER; ASHY TO SILTY TO COLLOIDAL TEXTURE; VERY HYDROPHILIC WITH MOST GOING INTO SOLUTION; SCATTERED FIRM BLEBS AND LAMINAE OF DEVITRIFIED ASH; SCATTERED THIN BEDS OF CARBON CLAY AND CARBONACEOUS SHALE. TUFFACEOUS SILTSTONE (4020'-4080') = LIGHT GRAY TO PINKISH GRAY; VERY SOFT; LUMPY TO CLUMPY; CLUSTERED TO CLOTTED; SLIGHTLY MUSHY IN PARTS; NON TO VERY SLIGHT Olson Creek #2 20 COHESIVE; SLIGHT TO MODERATE ADHESIVE; AMORPHOUS FRACTURE AND HABIT; DULL EARTHY LUSTER; ASHY TO SILTY TO COLLOIDAL TEXTURE; VERY HYDROPHILIC WITH MOST GOING INTO SOLUTION; SCATTERED FIRM BLEBS AND LAMINAE OF DEVITRIFIED ASH; OVERALL SILTY TO ASHY WITH GRADATIONAL MINOR CLAYS. TUFFACEOUS SILTSTONE (4080'-4110') = LIGHT GRAY; VERY SOFT; SLI MUSHY; SLI COHESIVE; MODERATELY ADHESIVE; MASSIVE CUTTINGS TO SLI NODULAR FROM TRANSPORT; IRREGULAR FRACTURE; SILTY TO CLAYEY TEXTURE; OCC THIN WHITE ASH LAMINATIONS; LOOSE DARK GRAY CARBONACEOUS SHALE; SOME LOOSE SILT AND VERY FINE QUARTZ IN SAMPLE TRAYS. COAL/CARBONACEOUS SHALE (4110'-4140') = DARK GRAY TO BLACK; SME BROWNISH HUES; MOD HARD; PLATY TO SLI FLAKY CUTTINGS; BLOCKY TO PLANAR FRACTURE; DULL TO RESINOUS LUSTER IN HIGHER GRADE COAL; SME CLAYSTONE BOUNDARIES INDICATING THINLY BEDDED IN CLAYSTONE; SME VISIBLE BLEEDING GAS; ASSOCIATED WITH MINOR GAS INCREASES. TUFFACEOUS SILTSTONE (4140'-4200') = LIGHT GRAY; WHITISH HUE FROM ASH; SOFT; MUSHY TO PASTY; HOMOGENEOUS SPECIMENS; IRREGULAR FRACTURE; CLAYEY TO SILTY TEXTURE; NON CALCAREOUS; DULL LUSTER; ASSOCIATED WITH ABUNDANT CARB SHALE/COAL FRAGMENTS; INTERBEDDED WITH COAL/CARBONACEOUS SHALE. TUFFACEOUS SILTSTONE(4200'-4290') = LIGHT GRAY TO LIGHT MEDIUM GRAY; SME WHITISH ASH SPECIMENS; SOFT; MUSHY TO PASTY; SLI NODULAR TO MASSIVE CTGS; DOM ADHESIVE CLAY; SILTY TO CLAYEY TEXTURE; POORLY PRESERVED IN SAMPLES; DULL LUSTER IN RARE PRESERVED SPECIMENS; ABUNDANT LOOSE CARB SHALE/COAL FRAGMENTS MINOR LOOSE WHITE ASH; INTERBEDDED WITH THIN COALS/CARBONACEOUS SHALE. COAL/CARBONACEOUS SHALE (4290'-4320') = DARK GRAY TO BLACK; ABUNDANT SPLINTERY TO PLATY TO FLAKY PIECES; MOD HARD; PLANAR TO BLOCKY FRACTURE; DULL EARTHY TO RESINOUS IN MORE COALY PIECES; SME VERY FINE LAMINATIONS; TRACE VISIBLE BLEEDING GAS; ASSOCIATED WITH MINOR GAS SHOWS. TUFFACEOUS SILTSTONE (4320'-4350') = LIGHT GRAY; DOMINANTLY PRESERVED AS MUSHY, SOFT HOMOGENEOUS CLAY; RARE LIGHT GRAY PRESERVED SPECIMENS; INCREASE IN LOOSE SAND CUTTINGS; INTERBEDDED WITH VERY FINE GRAINED SANDSTONE; CARBONACEOUS HALE/COAL FRAGMENTS; INTERBEDDED WITH THIN COALS. SANDSTONE/SAND(4380'-4410') = DOM AS LOOSE GRAIN; NO MATRIX PRESERVED; LOWER TO UPPER FINE GRAINED; MODERATE TO WELL SORTED; ANGULAR TO SUBANGULAR; LOW TO MOD SPHERICITY; TRACE VARICOLRED GRAINS; TRACE LOOSE WHITE ASH IN SAMPLE TRAYS; NO SIGNIFICANT INCREASE IN GAS. TUFFACEOUS SILTSTONE(4410'-4440') = LIGHT GRAY PRESERVED SPECIMENS; DOMINANT SOFT, MUSHY TO LUMPY HOMOGENEOUS CLAY; IRREGULAR FRACTURE; SME PRESERVED CUTTINGS; NON CALCAREOUS; SILTY TO SMOOTH TEXTURE; VARIABLE AMOUNTS OF SILT; OCC VERY SANDY; TRACE AMOUNT OF LOOSE WHITE ASH IN SAMPLE TRAYS; WITH ABUNDANT LOOSE COAL AND CARBONACEOUS SHALE IN SAMPLE TRAYS. SAND/SANDSTONE (4480'-4530') = DOM LOOSE GRAINS; DOM CLEAR TO TRANSLUCENT; TRACE BLACK TO LIGHT GREEN TO MOD GRAY VARICOLORED GRAINS; DOM LOWER FINE TO UPPER FINE GRAINED; ANGULAR TO SUBANG; MOD WELL SORTED; MOD SPHERICITY; NO MATRIX PRESERVED; NO HYDROCARBON INDICATORS. Olson Creek #2 21 TUFFACEOUS SILTSTONE(4530'-4560') = LIGHT GRAY; DOM MUSHY TO PASTY LIGHT GRAY CLAY; TRACE FIRM CLAYEY TO SILTY SPECIMENS; HOMOGENEOUS CLAY; IRREG FRACTURE; DULL EARTHY LUSTER; WITH LOOSE SILTY AND VERY FINE QUARTZ GRAINS; INTERBEDDED WITH THIN COALS. CARBONACEOUS SHALE/COAL (4530' -4405') = DOM AS LOOSE SPECIMENS RECOVERED FROM MUSHY TO PASTY HOMOGENEOUS CLAY; BLACK TO DARK GRAY; TRACE DARK BROWN SPECIMENS; MODERATELY HARD SMOOTH TO ROUGH TEXTURE; SME THIN LAMINATIONS OBSERVED; DULL TO SLI RESINOUS TO RARE VITREOUS LUSTER. TUFFACEOUS SILTSTONE (4605'-4690') = VERY LIGHT GRAY TO LIGHT GRAY; VERY POOR TO POORLY INDURATED; VERY SLIGHTLY SECTILE; OVERALL MUSHY TO PASTY; EARTHY FRACTURE; SUB NODULAR HABIT FROM WELL BORE EROSIONAL TRANSPORT; BRIGHT EARTHY LUSTER; SILTY TO CLAYEY TO ASHY TEXTURES MASSIVE HOMOGENEOUS TUFFACEOUS SILT COMPOSED OF 80% SILT, 20% VERY FINE SAND DEVITFRIFED ASH AND CARBON FINES; FIVE FOOT COALS AT 4630' AND 4650'. COAL/CARBONACEOUS SHALE (4690'-4760') = OCCURS AS THIN BEDS AND AS LAMINAE; BLACK MOTTLED BROWNISH BLACK; FIRM TO HARD IN LARGER CUTTINGS; EARTHY MOTTLED RESINOUS LUSTER; HACKLY TO SUBPLANAR TO BLOCKY TEXTURES FROM DIFFERENT GRADES OF CARBON SHALE AND LOW GRADE COAL; DISTINCT BANDS OF DIFFERING CARBON GRADE SLIGHT VISIBLE BLEEDING GAS FROM COALS. TUFFACEOUS SANDSTONE/SILTSTONE (4760'-4805') = GRADATIONAL BEDS OF SILT AND INTERBEDDED SANDS; VERY LIGHT GRAY; CLAST SIZE FINE LOWER TO VERY FINE LOWER GRADING TO SILT; SUB ROUND; WELL DEVELOPED SPHERICITY; VERY POOR SORTING; PLOSHED TEXTURE; IMMATURE NATURE; INTERBEDDED WITH TUFFACEOUS SILTSTONE WITH DOMINANT SILT/ASH MATRIX SUPPORT; LOOSELY ATTACHED AND HYDROPHILIC; POOR POROSITY AND PERMEABILITY; NO OIL INDICATORS. CARBONACEOUS SHALE/COAL (4805'-4850') = BLACK MOTTLED DUSKY BROWN; FIRM; EARTHY TO SUB RESINOUS LUSTER; MATTE TO SUB STRIATED TEXTURE; PLANAR FRACTURE ALONG CARBON SHALE PARTINGS TO HACKLY IN COALS PDC GROUND UP CUTTINGS; SLIGHT VISIBLE GRADE COAL; OCCURS AS THIN BEDS AND AS LAMINAE IN TUFFACEOUS SILTSTONES. TUFFACEOUS SILTSTONE/TUFFACEOUS CLAY (4850'-4865') = VERY LIGHT GRAY TO LIGHT GRAY SOME PINKISH GRAY; GRADATIONAL BEDS OF SILT AND CLAY; VERY POOR TO POORLY INDURATED; VERY SLIGHTLY SECTILE; MUSHY TO PASTY; EARTHY FRACTURE; SUB NODULAR HABIT FROM WELL BORE EROSIONAL TRANSPORT EARTHY LUSTER; CLAYEY TO SILTY TO ASHY TEXTURE; MASSIVE GRADATIONAL BEDS OF SILT AND SECONDARY CLAY. COAL/CARBONACEOUS SHALE (4865'-4945') = BLACK MOTTLED BROWNISH BLACK; FIRM; EARTHY TO SUB RESINOUS LUSTER; MATTE TO STRIATED TEXTURE; PLANAR FRACTURE IN CARBONACEOUS SHALE TO HACKLY IN LIGNITIC COALS SCATTERED THIN TO THICK BEDS. TUFFACEOUS SILTSTONE/TUFFACEOUS CLAY (4910'-4980') = VERY LIGHT GRAY TO LIGHT GRAY SOME PINKISH GRAY; GRADATIONAL BEDS OF SILT AND CLAY; VERY POOR TO POORLY INDURATED; VERY SLIGHTLY SECTILE; MUSHY TO PASTY; EARTHY FRACTURE; SUB NODULAR HABIT FROM WELL BORE EROSIONAL TRANSPORT. TUFFACEOUS SILTSTONE/TUFFACEOUS CLAY (4980'-5045') = VERY LIGHT GRAY TO LIGHT GRAY SOME PINKISH GRAY; GRADATIONAL BEDS OF SILT AND CLAY; VERY POOR TO POORLY Olson Creek #2 22 INDURATED; VERY SLIGHTLY SECTILE; MUSHY TO PASTY; EARTHY FRACTURE; SUB NODULAR HABIT FROM WELL BORE EROSIONAL TRANSPORT EARTHY LUSTER; CLAYEY TO SILTY TO ASHY TEXTURES; MASSIVE GRADATIONAL TUFFACEOUS SILT AND CLAY. COAL/CARBONACEOUS CLAY (5045'-5065') = BLACK MOTTLED DUSKY BROWN TO GRAYISH BLACK; FIRM; MATTE TEXTURE; HACKLY TO SUB BLOCKY FRACTURE; PDC GROUND UP CUTTINGS; LIGNITIC COAL WITH VISIBLE BLEEDING GAS. TUFFACEOUS SILTSTONE/CLAYSTONE (5065'-5130') = LIGHT GRAY TO MEDIUM LIGHT GRAY VERY POOR TO POORLY INDURATED; MUSHY TO PASTY; SLIMY IN PARTS; NON TO SLIGHTLY COHESIVE; SLIGHT TO MODERATE ADHESIVE; EARTHY FRACTURE; SUB NODULAR HABIT FROM WELL BORE EROSIONAL TRANSPORT; EARTHY LUSTER; SILTY TO CLAYEY TEXTURES; MASSIVE GRADATIONAL SILTS AND CLAYS WITH THIN TO THICK CARBON SHALE AND LOW GRADE LIGINITIC COAL WITH VISIBLE GAS BLEEDS. COAL/CARBONACEOUS CLAY (5130'-5175') = BLACK MOTTLED DUSKY BROWN TO GRAYISH BLACK; FIRM; MATTE TEXTURE; HACKLY TO SUB BLOCKY FRACTURE; PDC GROUND UP CUTTINGS; LIGNITIC COAL WITH VISIBLE BLEEDING GAS. TUFFACEOUS SILTSTONE/CLAYSTONE (5175'-5220') = LIGHT GRAY TO MEDIUM LIGHT GRAY VERY POOR TO POORLY INDURATED; MUSHY TO PASTY; SLIMY IN PARTS; NON TO SLIGHTLY COHESIVE; SLIGHT TO MODERATE ADHESIVE; EARTHY FRACTURE; SUB NODULAR HABIT FROM WELL BORE EROSIONAL TRANSPORT; EARTHY LUSTER; SILTY TO CLAYEY TEXTURES; MASSIVE GRADATIONAL SILTS AND CLAYS WITH THIN TO THICK CARBON SHALE AND COAL. TUFFACEOUS SILTSTON(5220'-5250') = LIGHT GRAY TO MEDIUM LIGHT GRAY; SOFT; MUSHY TO PASTY; SLIGHTLY PLATY IN RARE PRESERVED SPECIMENS; SME NODULAR HABIT FROM TRANSPORT; SLIGHTLY ADHESIVE; SILTY TO CLAYEY TEXTURE IN PRESERVED SPECIMENS; VARIABLE AMOUNTS OF SILT; TRACE AMOUNTS OF LOOSE WHITE ASH; THIN CARBONACEOUS SHALE/COAL INTERBEDS. SAND (5250'-5280') = DOM LOOSE CLEAR TO TRANSLUCENT GRAINS; LOWER FINE TO UPPER FINE GRAINED; ANGULAR TO SUBANGULAR; MOD WELL SORTED; MOD SPHERICITY; TRACE VARICOLRED GRAINS; NO MATRIX PRESERVED; GRADATIONAL TO AND INTERBEDDED WITH TUFFACEOUS SILTSTONE AND CLAYSTONE. COAL/CARBONACEOUS SHALE(5310'-5320') = BLACK; SOME DARK BROWNISH HUES; MOD HARD; PLATY TO BLOCKY CUTTINGS; PLANAR TO BLOCKY FRACTURE; SMOOTH TO ROUGH TEXTURE; SOME VISIBLE THIN LAMINATIONS; LOW GRADE COAL; RARE VISIBLE BLEEDING GAS; ASSOCIATED WITH 100+ UNIT GAS SHOWS THINLY BEDDED IN TUFFACEOUS CLAYSTONE AND SILTSTONE. TUFFACEOUS SANDSTONE(5370'- 5400') = LIGHT GRAY WHITE PRESERVED SPECIMENS; DOM LOOSE GRAINS; LOWER TO UPPER FINE GRAINED; MATRIX SUPPORTED; ANGULAR TO SUBANGULAR; MOD SPHERICITY; CLAY/ASH MATRIX; VERY FINE CARBONACEOUS MATERIAL; THINLY BEDDED IN TUFFACEOUS SILTSTONE; NO HYDROCARBONS. TUFFACEOUS SANDSTONE (5400'-5430') = LIGHT GRAY/GRAY WHITE; POORLY INDURATED SPECIMENS; LOWER FINE TO LOWER MEDIUM GRAINED; ANGULAR TO SUB ROUNDED; MOD SORTING; WHITE ASH/SILT MATRIX; TRACE LOOSE VARICOLORED GRAINS FROM RED TO LIGHT GREEN; TRACE LITHIC FRAGMENTS; LOOSE WHITE ASH IN SAMPLE TRAYS; NO HYDROCARBON INDICATORS. Olson Creek #2 23 TUFFACEOUS SILTSTONE (5430'-5490') = LIGHT GRAY; TRACE MEDIUM GRAY; POORLY INDURATED; PRESERVED SPECIMENS SLIPLATY; SME NODULAR CUTTINGS FROM TRANSPORT; CLAYEY TO SILTY TEXTURE; INCREASE IN SILT CONTENT; DULL LUSTER; SOME LOOSE WHITE ASH SPECIMENS IN SAMPLE TRAY; INCREASE IN LOOSE VERY FINE QUARTZ SAND. TUFFACEOUS SANDSTONE( 5490'-5550') = WHITE GRAY TO LIGHT GRAY; POORLY INDURATED; LOWER FINE TO UPPER MEDIUM GRAINED; ANGULAR TO SUBROUNDED; MOD SPHERICITY; WHITE ASH/SILT/CLAY MATRIX; DOM MATRIX SUPPORTED; TRACE VARICOLORED GRAINS; TRACE BROKEN CHERT; SOME THIN WHITE ASH LAMINATIONS. TUFFACEOUS SILTSTONE(5550'-5580') = LIGHT GRAY; TRACE MEDIUM DARK GRAY; SOFT; PASTY TO MUSHY; SLIGHT INCREASE IN FIRMNESS; SLIGHTLY PLATY TO SLIGHTLY NODULAR CUTTINGS; SOME VERY FINE CARBONACEOUS MATERIAL; CLAYEY TO SILTY; VARIABLE AMTS OF SILT; GRADING TO TUFFACEOUS CLAYSTONE LOOSE SILT TO VERY FINE QUARTZ GRAINS; INTERBEDDED WITH THIN COALS. TUFFACEOUS CLAYSTONE/SILTSTONE (5580'-5610') = LIGHT GRAY; POORLY INDURATED; SOFT TO MUSHY; CLAYEY TO SILTY TEXTURE; NON CALCAREOUS; DULL EARTHY LUSTER IN PRESERVED SPECIMENS; VERY FINE CARBONACEOUS; MATERIAL; VARIABLE AMOUNTS OF SILT; ABUNDANT LOOSE COAL/CARBONACEOUS SHALE IN SAMPLE TRAYS. COAL/CARBONACEOUS SHALE (5610'-5640') = BLACK; MOD HARD; SPLINTERY TO BLOCKY CUTTINGS; BLOCKY TO PLANAR FRACTURE; SMOOTH TO ROUGH TEXTURE; SLI RESINOUS LUSTER; NO VISIBLE BLEEDING GAS; ASSOC WITH 136 UNIT GAS INCREASE. TUFFACEOUS SILTSTONE(5640'-5730') = LIGHT GRAY; SOFT; POORLY INDURATED; SLI INCREASE IN FIRMNESS; SLI PLATY CUTTINGS; SILTY TEXTURE; SOME LOOSE WHITE ASH; THIN ASH LAMINATIONS; DULL EARTHY LUSTER; SLIGHT SANDY W/INCREASE IN LOOSE VERY FINE QUARTZ GRAINS. TUFFACEOUS SILTSTONE (5730'-5790') = LIGHT GRAY TO MEDIUM LIGHT GRAY PRESERVED SPECIMENS; SOFT TO MUSHY TO PASTY SPECIMENS; SME ORANGE HUES FROM ASH IN SAMPLE TRAYS; SLIGHTLY PLATY TO MASSIVE CUTTINGS; HOMOGENEOUS FRAC; SILTY TEXTURE DOMINANT; SME THIN WHITE ASH LAMINATIONS; VARIABLE SILT CONTENT; EASILY GRADING TO TUFFACEOUS CLAYSTONE; SCATTERED VERY FINE CARBONACEOUS MATERIAL; LOOSE WHITE ASH; LOOSE VERY FINE QUARTZ GRAINS; INTERBEDDED WITH COAL AND CARBON SHALE. COAL (5790-5820') = BLACK; SME DK BROWN HUES; MOD HARD; PLATY TO SPLINTERY CUTTINGS; RESINUOUS TO SLI VITREOUS LUSTER; PLANAR TO BLOCKY FRACTURE; SMOOTH TEXTURE; SME VISIBLE LAMINATIONS; SOME VISIBLE DEGASSING IN SPECIMENS. TUFFACEOUS SILTSTONE/TUFFACEOUS CLAY (5820'-5880') = VERY LIGHT GRAY TO LIGHT GRAY; VERY POOR TO POORLY INDURATED; MUSHY TO PASTY; VERY SLIGHT COHESIVENESS MODERATE ADHESIVE; EARTHY FRACTURE; SUB NODULAR HABIT FROM WELL BORE EROSIONAL TRANSPORT; EARTHY LUSTER; SILTY TO ASHY TO CLAYEY TEXTURE; MASSIVE GRADATIONAL BEDS OF TUFFACEOUS SILT AND TUFFACEOUS CLAY COMPOSED OF 70% SILT, 20% CLAY, 10% VERY FINE SAND, ASH AND CARBON FINES; THIN TO THICK COAL BEDS THROUGH OUT. COAL/CARBONACEOUS SHALE (5880'-5910') = BLACK MOTTLED BLACKISH GRAY TO DARK GRAY FIRM TO SOME HARD; EARTHY MOTTLED RESINOUS LUSTER IN TRUE COAL; HACKLY TO SUB PLANAR FRACTURE IN CARBON SHALE; PDC GROUND UP CUTTINGS; MICRO LAYERED AND Olson Creek #2 24 MICRO LAMINATED WITH ALTERING HUES OF CARBON SHALE TO LIGNITIC COAL. TUFFACEOUS SILTSTONE (5910'-5990') = LIGHT GRAY; VERY POOR TO POORLY INDURATED; MUSHY TO PASTY; VERY SLIGHTLY COHESIVE; MODERATE ADHESIVE; EARTHY FRACTURE; SUB NODULAR HABIT FROM WELL BORE EROSIONAL TRANSPORT; EARTHY LUSTER; SILTY TO ASHY TEXTURE; MASSIVE GRADATION OF TUFFACEOUS SILT; MICRO LAMINATIONS OF CARBON CLAY WITH PARALLEL LAMINAR PATTERNS. TUFFACEOUS SILTSTONE (6000'-6030') = LIGHT GRAY; POORLY INDURATED; MUSHY TO PASTY; SOME SLI PLATY CUTTINGS; EARTHY LUSTER; SILTY TEXTURE; SME THIN LAMINATIONS ON PRESERVED SPECIMENS; INTERBEDDED WITH THIN LOW GRADE COALS. TUFFACEOUS SANDSTONE(6030'-6060') = ABUNDANT LOOSE GRAINS; LIGHT GRAY PRESERVED SPECIMENS; LOWER FINE TO UPPER MEDIUM; TRACE BROKEN COARSE GRAINS; POORLY INDURATED; ANGULAR TO SUBANGULAR; ASH/SILT MATRIX; GRAIN TO MATRIX SUPPORTED; SME LOOSE VARICOLORED GRAINS; TRACE LOOSE WHITE SOFT ASH IN TRAYS; TRACE CHERT; MINOR GAS INCREASES OVER INTERVAL. TUFFACEOUS SANDSTONE (6090'-6150') = ABUNDANT CLEAR TO TRANSLUCENT GRAINS; LOWER TO UPPER FINE GRAINED; LIGHT GRAY TO LIGHT GRAY WHITE PRESERVED SPECIMENS; ANGULAR TO SUBROUNDED; MODERATE WELL SORTED; LOW TO MOD SPHERICITY; ABUNDANT LOOSE WHITE ASH MATRIX MATERIAL; DOMINANT ASH/SILT MATRIX; SOME ASH LAMINATIONS; TRACE LIGHT GRAY CHERT; SOME THIN CARBONACEOUS LAMINATIONS; ONLY A SLIGHT INCREASE IN GAS BACKGROUND. COAL (6150'-6180') = BLACK; MOD HARD; PLATY TO FLAKY TO BLOCKY CUTTINGS; BLKY TO PLANAR FRACTURE; RESINOUS TO VITREOUS LUSTER; SMOOTH TO ROUGH TEXTURE; SOME LAMINATED SPECIMENS; PLANT IMPRESSIONS; TRACE VISIBLE BLEEDING GAS FROM SPECIMEN THICKER HIGHER GRADE COAL WITH GAS SHOWS. TUFFACEOUS SILTSTON (6180'-6210') = LIGHT GRAY; SOFT; MUSHY TO PASTY; SLI INCREASE IN FIRMNESS; MASSIVE TO SLI PLATY TO SLI NODULAR CUTTINGS; CLAYEY TO SILTY TEXTURE; SME LOOSE WHITE ASH SPECIMENS; SLI ADHESIVE; SANDY IN PART; VERY FINE CARBONACEOUS MATERIAL. TUFFACEOUS SANDSTONE (6210'-6300') = ABUNDANT LOOSE GRAINS; LIGHT GRAY TO WHITE LIGHT GRAY PRESERVED SPECIMENS; POORLY INDURATED; LOWER FINE TO LOWER MEDIUM GRAINED; ANGULAR TO SUBANGULAR; LOW SPHERICITY; ASH/SILT MATRIX; GRAIN TO MATRIX SUPPORTED; LIGHT RED BROWN GRAINS; TRACE LIGHT GREEN UNIDENTIFIED GRAINS; MOD SORTED; SME SPECKLED BLACK GRAINS IN MATRIX; TRACE BROKEN LIGHT TO DARK GRAY CHERT GRAINS; ONLY SLIGHT INCREASE IN GAS BACKGROUND OVER INTERVAL TUFFACEOUS SILTSTONE/CLAYSTONE (6300'-6330') = LIGHT GRAY; SME LIGHT MEDIUM GRAY; SOFT; MUSHY IN PART; SLI PLATY CUTTINGS; HOMOGENEOUS FRACTURE; NON CALCAREOUS; SMOOTH TO SILTY TEXTURE; VARIABLE AMOUNTS OF SILT; INTERBEDDED WITH COAL. COAL (6330'-6360') = BLACK; MOD HARD; PLATY TO BLOCKY CUTTINGS; BLOCKY TO PLANAR FRACTURE; SMOOTH TEXTURE; RESINOUS TO VITREOUS LUSTER; SOME VISIBLE BLEEDING GAS; ASSOCIATED WITH 196 UNIT GAS SHOW; THICK BED. TUFFACEOUS CLAYSTONE(6360'-6390') = LIGHT GRAY; SOFT; POORLY INDURATED; INCREASE IN FIRMNESS; SLI PLATY TO NODULAR CUTTINGS FROM TRANSPORT; EARTHY FRACTURE; NON Olson Creek #2 25 CALCAREOUS; CLAYEY TEXTURE; DULL LUSTER; SILTY IN PART; GRADING TO TUFFACEOUS SILTSTONE; SOME LOOSE SILT AND VERY FINE QUARTZ; INTERBEDDED WITH THICK COALS. COAL (6400-6470') = BLACK TO DARK GRAY; MOD HARD; FLAKY TO ELONGATED TO BLOCKY CUTTINGS; BLOCKY TO PLANAR FRACTURE; SMOOTH TEXTURE; RESINOUS TO VITREOUS LUSTER; SME THIN LAMINATIONS; VISIBLE BLEEDING GAS; INTERBEDDED WITH CARB SHALE AND CLAYSTONE; VERY THICK COAL SECTION; ASSOCIATED WITH MULTIPLE GAS SHOWS FROM 112 UNITS TO 183 UNITS. TUFFACEOUS SILTSTONE GRADING TO TUFFACEOUS SANDSTONE (6470'-6580') = PINKISH GRAY TO VERY PALE ORANGE; VERY POORLY INDURATED; BRITTLE IN SANDSTONE; NON TO VERY SLIGHT COHESIVE; SLIGHTLY ADHESIVE; EARTHY FRACTURE; SUB NODULAR HABIT FROM WELL BORE EROSIONAL TRANSPORT EARTHY LUSTER; SILTY TO ASHY TEXTURE; MASSIVE GRADATIONAL TUFFACEOUS SILT AND GRADING TO TUFFACEOUS SANDSTONE INTER BEDDED LITHIC TUFF FRAGMENTS AND DEVITRIFIED ASH BLEBS AND CARBON FINES; MICRO LAMINAE OF CARBON CLAY. COAL/CARBONACEOUS SHALE (6580'-6600') = PREDOMINANTLY BLACK BECOMING BROWNISH BLACK TO GRAYISH BLACK NEAR TOP CONTACT; FIRM TO HARD; RESINOUS LUSTER BECOMING EARTHY NEAR TOP CONTACT; MATTE TEXTURE; HACKLY TO SUB CONCHOIDAL FRACTURE; VISIBLE BLEEDING GAS FROM MOST CUTTINGS; DOMINANT BITUMINOUS COAL. SAND/TUFFACEOUS SAND (6630'-6690') = VERY LIGHT GRAY; CLAST SIZE MEDIUM LOWER TO VERY FINE UPPER; MEAN SIZE FINE; SUB ANGULAR TO SUB ROUND; MODERATE DEVELOPED SPHERICITY; GENERAL EQUANT GRAIN DIMENSIONS; MODERATE TO SOME POOR SORTING; IMPACTED TEXTURE; MATURE TO SUB MATURE NATURE; UNCONSOLIDATED CLEAN ARENACEOUS SAND TO WEAKLY CONSOLIDATED SANDSTONE GRADING TO TUFFACEOUS SAND WITH ASH MATRIX SUPPORT; GRAIN SUPPORT TO MATRIX SUPPORT: HETROGENEOUS; GOOD TO FAIR POROSITY AND PERMEABILITY; NO OIL INDICATORS. TUFFACEOUS SILTSTONE (6690'-6755') = PALE YELLOWISH BROWN TO PINKISH GRAY AND VARIOUS HUES; POOR INDURATION; MUSHY; SLIGHTLY COHESIVE; SLIGHT TO MODERATE ADHESIVE; EARTHY FRACTURE; SUB NODULAR HABIT FROM WELL BORE EROSIONAL TRANSPORT EARTHY LUSTER; SILTY TO CLAYEY TEXTURE; MASSIVE GRADATIONAL BEDS OF TUFFACEOUS SILTSTONE COMPOSED OF 80% SILT, 20% VERY FINE SAND, CARBON FINES AND VARIOUS DETRITAL MATERIAL. COAL/CARBONACEOUS SHALE (6755'-6810') = BLACK MOTTLED BROWNISH BLACK AT CONTACTS AND GRAYISH BLACK AT MASS; FIRM TO HARD; EARTHY MOTTLED RESINOUS LUSTER; MATTE TEXTURE; BLOCKY TO HACKLY FRACTURE; DISTINCT VISIBLE BANDS OF DIFFERING CARBON MATURITY; VISIBLE BLEEDING GAS FROM MATURE COALS; APPEARS AS TWO THICK COALS WITH CARBON SILT AND TUFFACEOUS SILTSTONE BETWEEN. TUFFACEOUS SANDSTONE/SILTSTONE (6810'-6845') =VERY PALE ORANGE (ASH); CLAST RANGE VERY FINE UPPER TO SILT; SUB ROUND TO SUB ANGULAR; MODERATE DEVELOPED SPHERICITY; VERY POOR SORTING; IMMATURE TEXTURE; DOMINANT ASHSILT MATRIX SUPPORT GRADING TO TUFFACEOUS SILTSTONE AND THIN BEDS TO DEVITRIFIED ASH AND RAREER TUFF; POOR POROSITY AND PERMEABILITY; NO OIL INDICATORS. TUFFACEOUS SILTSTONE (6845'-6900') = PINKISH GRAY; VERY POOR TO POORLY INDURATED; BRITTLE; NON TO SLIGHTLY COHESIVE; SLIGHTLY ADHESIVE; EARTHY FRACTURE; SUB NODULAR HABIT FROM WELL BORE EROSIONAL TRANSPORT; HYDROPHILIC; EARTHY LUSTER; Olson Creek #2 26 SILTY TO ASHY TEXTURES; MASSIVE GRADATIONAL TUFFACEOUS SILT COMPOSED OF 80% SILT, 20% CLAY, VERY FINE SAND, TUFF, ASH, CARBON FINES AND VARIOUS DETRITAL MATERIAL. TUFFACEOUS SILTSTONE (6900'-6960') = PINKISH GRAY; VERY POOR TO POORLY INDURATED; BRITTLE; NON TO SLIGHTLY COHESIVE; SLIGHTLY ADHESIVE; EARTHY FRACTURE; SUB NODULAR HABIT FROM WELL BORE EROSIONAL TRANSPORT; HYDROPHILIC; EARTHY LUSTER; SILTY TO ASHY TEXTURES; MASSIVE GRADATIONAL TUFFACEOUS SILT COMPOSED OF 80% SILT, 20% CLAY, VERY FINE SAND, TUFF, ASH, CARBON FINES AND VARIOUS DETRITAL MATERIAL. TUFFACEOUS SANDSTONE/DEVITRIFIED ASH (6960'-7030') = PINKISH GRAY TO PALE YELLOWISH BROWN; CLAST SIZE MEDIUM LOWER TO VERY FINE UPPER; SUB ANGULAR TO SUB ROUND; MODERATE DEVELOPED SPHERICITY; POOR SORTING; IMPACT TO CHIP TEXTURE; IMMATURE NATURE DOMINANT SILT/ASH MATRIX SUPPORT; PORE FILLING AND ACTING AS A LITHIFIYING AGENT; GRADING TO ASH AND LITHIC TUFF; POOR POROSITY AND VERY POOR PERMEABILITY; APPEARS REWORKED AND DEPOSITED; NO OIL INDICATORS. TUFFACEOUS SILTSTONE (7030'-7090') = LIGHT GRAY; SOFT; SLI NODULAR TO SLIGHTLY PLATY CUTTINGS; EARTHY FRACTURE; CLAYEY TO SILTY TEXTURE; SOME SANDY EXAMPLES; GRADING TO TUFFACEOUS SANDSTONE; SME LOOSE LT BROWN/WHITE ASH IN SAMPLE TRAYS; SME VERY FINE CARBONACEOUS MATERIAL; INTERBEDDED WITH COALS. COAL (7090'-7110') = BLACK; SOME BROWNISH HUES; MOD HARD; PLATY TO BLOCK CUTTINGS; BLOCKY TO HACKLY FRACTURE; RESINOUS LUSTER IN LOW GRADE SPECIMENS TO VITREOUS; SMOOTH TO ROUGH TEXTURE; TRACE VISIBLE BLEEDING GAS; INTERBEDDED IN TUFFACEOUS CLAYSTONES AND SILTSTONES. TUFFACEOUS SANDSTONE (7140'-7200') = LIGHT GRAY TO LIGHT GRAY WHITE; LIGHT BROWNISH HUES FROM MUD; POORLY INDURATED; ABUNDANT LOOSE GRAINS; LOWER FINE TO LOWER MEDIUM GRAINED; ANGULAR TO SUBANGULAR; MOD WELL SORTED; DOM WHITE ASH MATRIX; MATRIX SUPPORTED; SME WHITE ASH LAMINATIONS; TRACE LIGHT GREEN AND REDDISH PARTICLES; SME VERY FINE MICA; NO GAS SHOWS. TUFFACEOUS SANDSTONE (7200'-7230') = ABUNDANT LOOSE CLEAR TO TRANSLUCENT GRAINS; LIGHT GRAY TO MIXED LIGHT GRAY WHITE; LIGHT BROWNISH HUES FROM MUD; SOFT; POORLY INDURATED; DOM LOWER FINE TO LOWER MEDIUM GRAINED; MOD WELL SORTED; ANGULAR TO SUBROUNDED; LOW SPHERICITY; DOM ASH MATRIX SUPPORTED; ABUNDANT ASH MATRIX MATERIAL IN SAMPLE TRAYS; VERY FINE CARBONACEOUS MATERIAL; NO SIGNIFICANT GAS INCREASES OVER INTERVAL. TUFFACEOUS SILTSTONE(7260'-7290') = LIGHT GRAY; SME BROWNISH HUES FROM MUD; SOFT; MASSIVE CUTTINGS; SOFT; IRREG FRACTURE; SILTY TEXTURE; SME WHITE ASH LAMINATIONS; SLIGHTLY ADHESIVE; NON CALCAREOUS; SANDY IN PART; GRADING TO TUFFACEOUS SANDSTONE. COAL (7310'-7330') = BLACK TO DARK GRAY; MOD HARD; PLATY TO BLOCKY TO SPLINTERY CUTTINGS; BLOCKY FRACTURE; RESINOUS TO VITREOUS LUSTER; SMOOTH TO SLI ROUGH TEXTURE; SME VISIBLE LAMINATIONS; SME VISIBLE BLEEDING GAS; ASSOCIATED WITH 253 UNIT GAS INCREASE; THICK COAL. TUFFACEOUS SANDSTONE(7320'-7380') = LIGHT GRAY; ABUNDANT LOOSE GRAINS; SOFT; LOWER FINE TO UPPER MEDIUM GRAINED; ANGULAR TO SUBANGULAR; MOD WELL SORTED; LOW SPHERICITY; DOM WHITE ASH MATRIX; MATRIX SUPPORTED; LOOSE WHITE ASH MATRIX MATERIAL IN SAMPLE TRAYS; NO SIGNIFICANT GAS INCREASE OVER INTERVAL. Olson Creek #2 27 TUFFACEOUS SANDSTONE(7380'-7410') = WHITE TO LIGHT GRAY WHITE; SME BROWN HUES FROM MUD SYSTEM; ABUNDANT LOOSE GRAINS; LOWER FINE TO UPPER MEDIUM GRAINED; MOD SORTED; ANGULAR TO SBANG; ABUNDANT LOOSE WHITE ASH IN SAMPLE TRAYS; DOM ASH/SILT MATRIX; MATRIX SUPPORTED; NO INCREASE IN GAS BACKGROUND COAL (7410'-7440') = BLACK TO DARK GRAY; SME DARK GRAY CARBONACEOUS SHALE; MOD HARD; BLOCKY TO FLAKY TO SPLINTERY CUTTINGS; BLOCKY TO SPLINTERY CUTTINGS; SMOOTH TO ROUGH TEXTURE; SME THIN CARBONACEOUS LAMINATIONS; VISIBLE LAMINATIONS; SME VISIBLE BLEEDING GAS; ASSOCIATED WITH GAS SHOWS. SAND/SANDSTONE (7470'-7585') = DOM LOOSE QUARTZ GRAINS; DOM CLEAR TO TRANSLUCENT GRAINS; SME LIGHT GREEN TO WHITE TO LIGHT RED GRAINS; TRACE LITHICS; LOWER FINE TO LOWER MEDIUM GRAINED; ANGULAR TO SUBANGULAR; MOD WELL SORTED; LOW SPHERICITY; TRACE MATRIX SUPPORTED SPECIMENS WITH WHITE ASH; TRACE BLACK CARBONACEOUS SHALE BOUNDARIES WHICH IMPLIES INTERBEDDING WITH CARB SHALE CONTINUED VERY CLEAN UNCONSOLIDATED SAND TO 7585'; DOMINANT GRAIN SUPPORTED; ARENACEOUS; GOOD POROSITY/PERMEABILITY. COAL (7585'-7640') = BLACK; FIRM TO HARD; RESINOUS LUSTER; MATTE TEXTURE; HACKLY FRACTURE; COMPOSED OF CLEAN (NO CLAY) BITUMINOUS COAL; ABUNDANT VISIBLE BLEEDING GAS FROM MOST CUTTINGS; OCCURS AS MAIN BED WITH SECONDARY MINOR BED AT 7635'-7645'. TUFFACEOUS SANDSTONE/SAND (7640'-7685') = VERY LIGHT GRAY TO PINKISH GRAY (ASH HUE CLAST SIZE MEDIUM LOWER TO VERY FINE LOWER GRADING TO SILT IN PARTS; SUB ANGULAR TO SUB ROUND; MODERATE DEVELOPED SPHERICITY; TRACE PROLATED GRAINS; VERY POOR SORTING; IMPACT TO PITTED TO CHIP TEXTURES; IMMATURE NATURE BECOMING MORE MATURE IN PARTS; BOTH GRAIN AND ASH/TUFF MATRIX SUPPORTED; ABUNDANT ASH MATRIX IS PORE FILLING AND ACTS AS A LITHIFYING AGENT GRADES TO ARENACEOUS CLEAN SAND; COAL/CARBONACEOUS SHALE (7685'-7710') = BLACK TO BROWNISH BLACK AT CONTACTS; FIRM TO HARD; RESINOUS TO EARTHY LUSTER IN CARBON SHALE; MATTE TEXTURE; HACKLY FRACTURE; LIGNITIC COAL TO CARBONACEOUS SHALE; VISIBLE BLEEDING GAS FROM MOST CUTTINGS. TUFFACEOUS SILTSTONE (7710'-7800') = PALE YELLOWISH BROWN TO PINKISH GRAY; POOR INDURATION; BRITTLE TO SLIGHTLY MUSHY; SLIGHTLY COHESIVE; SLIGHTLY ADHESIVE; EARTHY FRACTURE; SUB NODULAR HABIT FROM EROSIONAL WELL BORE TRANSPORT EARTHY LUSTER; ASHY TO SILTY TEXTURES; MASSIVE GRADATIONAL BEDS OF ASHY SILTS WITH CARBONACEOUS CLAYS DISPLAYING MICRO LAYERED AND MICRO LAMINATED BLACK CARBONACEOUS CLAY IN PARTS GRADING TO CARBONACEOUS SHALE IN THIN BEDS. TUFFACEOUS SILTSTONE (7800'-7850') = PALE YELLOWISH BROWN TO PINKISH GRAY; POOR INDURATION; BRITTLE TO SLIGHTLY MUSHY; SLIGHTLY COHESIVE; SLIGHTLY ADHESIVE; EARTHY FRACTURE; SUB NODULAR HABIT FROM EROSIONAL WELL BORE TRANSPORT EARTHY LUSTER; ASHY TO SILTY TEXTURES; MASSIVE GRADATIONAL BEDS OF ASHY SILTS WITH CARBONACEOUS CLAYS DISPLAYING MICRO LAYERED AND MICRO LAMINATED BLACK CARBON 7855'-7870' WITH VISIBLE BLEEDING GAS. COAL/CARBONACEOUS SHALE (7860') = DARK GRAY; BLACK; SME DARK BROWNISH HUES; FIRM TO MOD HARD; PLATY TO ELONGATED CUTTINGS; BLOCKY TO SPLINTERY FRACTURE; DULL TO Olson Creek #2 28 RESINOUS LUSTER; SME VITREOUS EXAMPLES IN HIGER GRADE COAL; SOME VISIBLE BLEEDING GAS; INTERBEDDED IN TUFFACEOUS SILTSTONE. TUFFACEOUS SILTSTONE(7890'-7920') = LIGHT GRAY; VARIOUS BROWNISH HUES FROM MUD; SOFT TO SLI MUSHY; MASSIVE TO SLI PLATY; VARIABLE AMTS OF SILTY; CLAYEY TO SILTY TEXTURE; DULL LUSTER; SOME THIN CARBONACEOUS LAMINATIONS; INTERBEDDED WITH THIN COALS. SAND/TUFFACEOUS SANDSTONE (7950'- 8010') = DOMINANTLY LOOSE GRAINS; WHITE TO CLEAR TO TRANSLUCENT; TRACE SOFT WHITE GRAY PRESERVED SPECIMENS; SME LIGHT BROWNISH SPECIMENS FROM MUD; UPPER FINE TO LOWER MEDIUM GRAINED; ANGULAR TO SUBANGULAR; LOW SPHERICITY MODERATE WELL SORTED; TRACE WHITE ASH MATRIX MATERIAL; LIGHT GREEN GRAINS; TRACE LT BROWN BIOTITE; TRACE LIGHT GRAY CHERT; TRACE LITHIC FRAGMENTS; SLIGHT GAS INCREASE OVER INTERVAL; NO SAMPLE SHOWS. COAL/CARBONACEOUS SHALE (8010'-8040') = BLACK; SOME DARK BROWN CARBONACEOUS SPECIMENS; MOD HARD; PLATY TO FLAKY CUTTINGS; BLOCKY FRACTURE; RESINOUS TO VITREOUS LUSTER IN HIGHER GRADE COAL; SOME VISIBLE LAMINATIONS; SME VISIBLE BLEEDING GAS. TUFFACEOUS SILTSTONE/CLAYSTONE (8040'-8100') = LIGHT GRAY TO MEDIUM LIGHT GRAY; SOFT; NODULAR TO MASSIVE CUTTINGS; IRREGULAR FRACTURE; CLAYEY TO SILTY TEXTURE; DULL EARTHY LUSTER; SME FINE LAMINATIONS; SME THIN VERY FINE CARB LAMINATIONS; VARIABLE AMOUNTS OF SILT; INTERBEDDED WITH THIN CARBONACEOUS SHALE AND COAL. TUFFACEOUS SILTSTONE (8100-8130') = LIGHT GRAY TO MEDIUM LIGHT GRAY; SOFT; SLI PLATY TO SLI NODULAR FROM TRANSPORT; EARTHY TO IRREGULAR FRACTURE; CLAYEY TO SILTY TEXTURE; DULL EARTHY LUSTER; GRADES TO TUFFACEOUS CLAYSTONE; VARIABLE AMOUNTS OF SILT; MASSIVE, HOMOGENOUS STRUCTURE. SAND/TUFFACEOUS SANDSTONE (8150'-8180') = DOMINANT LOOSE GRAINS; SME PRESERVED SPECIMENS WITH WHITE ASH MATRIX MATERIAL ATTACHED; UPPER FINE TO LOWER MEDIUM GRAINED; ANGULAR TO SUBANGULAR; MOD SORTING; LOW SPHERICITY; SME SCATTERED UNIDENTIFIED BLACK GRAINS; SILT/ASH MATRIX; SLIGHT GAS INCREASE OVER SAMPLE INTERVAL; NO SAMPLE SHOWS. TUFFACEOUS SILTSTONE (8180'-8260') =VERY LIGHT GRAY; SME BROWNISH HUES FROM MUD; SOFT; MASSIVE TO SLI PLATY TO NODULAR CUTTINGS FROM TRANSPORT; EARTHY TO IRREGULAR FRACTURE; VERY FINE SCATTERED CARBONACEOUS MATERIAL; VERY FINE CARBONACEOUS LAMINATIONS; SANDY IN PART; GRADING TO AND INTERBEDDED WITH TUFFACEOUS SANDSTONE. COAL (8260'-8290') = BLACK; DOM COAL W/MINOR CARBONACEOUS SHALE; HARD; BLOCKY TO PLATY CUTTINGS; BLOCKY FRACTURE; DOM VITREOUS LUSTER- HIGHER GRADE COAL; SMOOTH TEXTURE; ABUNDANT DEGASSING SPECIMENS IN SAMPLE TRAYS; ASSOCIATED WITH MULTIPLE GAS SHOWS. MAX GAS 275U. TUFFACEOUS SILTSTONE (8290'-8360') = LIGHT GRAY TO MEDIUM GRAY SOME PINKISH GRAY AND VARIOUS HUES OF BOTH; FIRM; STIFF; MODERATE CHOESIVE; NON ADHESIVE; CUTTINGS HAVE DISTINCT HARDNESS CHANGE; EARTHY FRACTURE; SUB NODULAR HABIT FROM WELL BORE EROSIONAL TRANSPORT; EARTHY LUSTER; SILTY TO GRITTY SOME ABRASIVE TEXTURE; Olson Creek #2 29 MASSIVE FIRM GRADATIONAL SILT; TRACE TUFF AND CARBON FINES; SCATTERED MICRO LAYERED CARBON LAMINAE GRADING TO SMALL COALS 8310'-8340'. COAL/CARBONACEOUS SHALE (8360'-8375') = BLACK TO BROWNISH BLACK IN CARBON CLAY; CARBON CLAY IS SOFT WITH EARTHY LUSTER WITH SUBPLANAR FRACTURE WITH MICRO LAMINATED AND LAYERED WITH CARBON CLAY; COAL IS FIRM TO HARD; RESINOUS LUSTER; HACKLY FRACTURE. TUFFACEOUS SILTSTONE (8375'-8460') = PINKISH GRAY TO LIGHT BROWNISH GRAY; POOR INDURATION; MUSHY; SLIGHTLY COHESIVE, SLIGHTLY ADHESIVE; EARTHY FRACTURE; SUB NODULAR HABIT FROM WELL BORE EROSIONAL TRANSPORT; EARTHY LUSTER; SILTY TO ASHY TEXTURE; MASSIVE GRADATION OF TUFFACEOUS ASHY SILT COMPOSED OF 70% SILT, 20% VERY FINE SAND, 10% ASH, CARBON FINES AND VARIOUS DETRITAL. TUFFACEOUS SILTSTONE (8480'-8520') = LT GRAY WITH BROWNISH HUES FROM MUD SYSTEM; SOFT; MASSIVE TO SLIGHTLY PLATY CUTTINGS EARTHY TO IRREGULAR FRACTURE; DULL EARTHY LUSTER; SMOOTH TO SILTY TEXTURE; VARIABLE AMOUNTS OF SILT; GRADING TO TUFFACEOUS CLAYSTONE; INTERBEDDED WITH THICK, BLACK, VITREOUS COAL F/8510' TO 8540'. VISIBLE BLEEDING GAS FROM COAL ASSOCIATED WITH GAS SHOW. SAND/TUFFACEOUS SANDSTONE (8550'-8580') = DOMINANTLY LOOSE SAND GRAINS; MINOR PRESERVED WHITE, TUFFACEOUS SANDSTONE SPECIMENS; LOWER TO UPPER FINE GRAINED; ANGULAR TO SUBANGULAR; TRACE LOOSE WHITE ASH MATRIX MATERIAL IN SAMPLE TRAYS; TRACE JASPER; TRACE GREEN GRAINS; NO GAS INCREASE OVER INTERVAL. CONGLOMERATE SAND/SAND/ASH (8550'-8705') = VERY LIGHT GRAY TO PINKISH GRAY/WHITE IN ASH; CLAST SIZE VERY COARSE LOWER TO FINE LOWER; ANGULAR BIT IMPACTED VERY COARSE TO COARSE GRAINS TO SUB ANGULAR TO SUB ROUND MEDIUM TO FINE GRAINS; LOW TO MODERATE DEVELOPED SPHERICITY; VERY POOR SORTING; BIMODAL WITH DEPARATE MODE PRIMARY MEDIUM/FINE GRAIN TO SECONDARY VERY COARSE TO COARSE; IMPACT TO CHIP TEXTURES; IMMATURE TO MATURE NATURE; UNCONSOLDIATED SAND WITH WHITE VERY SOFT DEVITRIFIED ASH BEDS DECREASING BY 8670' SAND IS GRAIN SUPPORTED WITH MODERATE ASH CONTENT OCCURING AS THIN BEDS OR POSSIBLE INTERBEDDED; POOR TO GOOD POROSITY AND PERMEABILITY; COMPOSED OF DOMINANT QUARTZ, SECONDARY CHERT, TRACE ARGILLITE (SILICEOUS MUDSTONE), FELDSPAR NO SHOW OIL INDICATORS. TUFFACEOUS SILTSTONE (8705'-8730') = LIGHT BROWNISH GRAY TO RARE LIGHT GRAY; POOR INDURATION; BRITTLE; SLIGHTLY COHESIVE; SLIGHTLY ADHESIVE; EARTHY FRACTURE; SUB NODULAR TO SUB PLANAR HABIT; EARTHY LUSTER; SILTY TEXTURE; MASSIVE GRADATION OF TUFFACEOUS SILT COMPOSED OF 80% SILT, 20% ASH, CARBONACEOUS FINES AND VARIOUS DETRITAL MATERIAL. COAL/CARBON CLAY (8730'-8755') = BLACK MOTTLED BROWNISH BLACK TO GRAYISH BLACK; FIRM TO HARD; RESINOUS MOTTLED EARTHY LUSTER; MATTE TEXTURE; HACKLY TO SUB CONCHOIDAL FRACTURE; VISIBLE BLEEDING GAS BECOMING MORE CARBON CLAY AY 8750' GRADING TO ASHY SILTS. TUFFACEOUS SILTSTONE (8755'-8850') = LIGHT BROWNISH GRAY TO PALE YELLOWISH BROWN; POOR INDURATED; POOR INDURATED; BRITTLE; SLIGHTLY COHESIVE; SLIGHTLY ADHESIVE; PDC GROOVED FRACTURE AND HABIT DULL EARTHY LUSTER; ASHY TO SILTY TEXTURE; MASSIVE TUFFACEOUS SILT. Olson Creek #2 30 TUFFACEOUS SILTSTONE (8850'-8910') = LIGHT GRAY TO LIGHT BROWNISH GRAY (FROM MUD); BECOMING WHITE GRAY AT 8910'. SOFT AND POORLY INDURATED; MASSIVE TO SLIGHTLY PLATY CUTTINGS; SLIGHTLY ADHESIVE; EARTHY TO IRREGULAR FRACTURE; DULL EARTHY LUSTER; ASHY TO SILTY TEXTURE; ASH INTERBEDS; BECOMING SANDY WITH VERY FINE QUARTZ AT BASE; FINE CARBONACEOUS LAMINATIONS; INTERBEDDED WITH THIN BLACK TO BROWN CARBONACEOUS SHALE AND BLACK, VITREOUS COAL INTERVALS. TUFFACEOUS SILTSTONE (8910'-8940') = LIGHT GRAY; SME WHITE SPECIMENS; BROWNISH HUES FROM MUD; SOFT; POORLY INDURATED; MASSIVE TO SLIGHT PLATY CUTTINGS; IRREGULAR FRACTURE; SANDY IN PART; GRADING TO TUFFACEOUS SANDSTONE SOME WHITE LOOSE ASH IN SAMPLE TRAYS; INTERBEDDED WITH THIN, BLACK, VITREOUS COALS WITH ASSOCIATED GAS SHOWS. CONGLOMERATIC SANDSTONE/SAND (8970'-9000') = ABUNDANT LOOSE GRAINS; TRACE LIGHT GRAY/GRAY WHITE PRESERVED SPECIMENS; COARSE TO UPPER FINE GRAINED; ANGULAR TO SUBROUNDED; POORLY SORTED; LOW SPHERICITY; TRACE WHITE ASH MATRIX MATERIAL; LOW SPHERICITY; TRACE COARSE BROKEN CHERT; TRACE JASPER; TRACE LITHIC FRAGMENTS; ASH/SILT/ MATRIX; SLIGHT GAS INCREASE OVER INTERVAL. TUFFACEOUS SILTSTONE (9000'-9030') = LIGHT GRAY; BROWNISH HUES; SME WHITE ASH INTERBEDS; SOFT; SLIGHTLY PLATY TO MASSIVE CUTTINGS; EARTHY FRACTURE; VARIABLE AMOUNTS OF SILT; SANDY IN PART; GRADING TO VERY FINE GRAINED TUFFACEOUS SANDSTONE. COAL (9060'-9070') = BLACK; MOD HARD; PLATY TO FLAKY TO BLOCKY CUTTINGS; PLANAR FRACTURE; VITREOUS LUSTER; SOME RESINOUS LUSTER IN CARBONACEOUS SHALE EXAMPLES; SMOOTH TEXTURE; SOME VISIBLE BLEEDING GAS IN SPECIMENS; ASSOCIATED WITH 152 U GAS SHOW. TUFFACEOUS SILTSTONE (9100'-9150) = LIGHT GRAY; BROWNISH GRAY FROM MUD; SOFT; MASSIVE TO SLIGHTLY CUTTINGS; EARTHY FRACTURE; VARIABLE AMOUNT OF SILT; GRADING TO TUFFACEOUS SANDSTONE; CLAYEY TO SILTY TEXTURE; THIN CARBON LAMINATIONS; SOME LOOSE WHITE ASH. SAND/TUFFACEOUS SANDSTONE (9150'-9170') = DOMINANT LOOSE GRAINS; SME SOFT WHITE GRAY PRESERVED SPECIMENS; LOWER FINE TO UPPER FINE GRAINED; ANGULAR TO SUBANGULAR; LOW SPHERICITY; SME WHITE ASH/SILT LOOSE MATRIX SPECIMENS; TRACE LIGHT GREEN, RED GRAINS; TRACE GRAY CHERT; NO SIGNIFICANT GAS INCREASES OVER INTERVAL. COAL/CARBONACEOUS SHALE (9190'-9200') = BLACK; SME DARK BROWN CARB SHALE; MOD HARD; PLATY TO FLAKY TO BLOCKY CUTTINGS; BLOCKY FRACTURE; SMOOTH TO ROUGH TEXTURE; RESINOUS IN CARBONACEOUS SHALE EXAMPLES; VITREOUS LUSTER IN HIGH GRADE SAND/TUFFACEOUS SANDSTONE (9200'-9295') = VERY LIGHT GRAY; CLAST SIZE FINE LOWER TO VERY FINE LOWER; SUB ANGULAR; LOW DEVELOPED SPHERICITY WITH COMMON PROLATE AND DISCOIDAL GRAINS; MODERATE SORTING; UNCONSOLIDATED; MATURE TO SUB MATURE NATURE; DOMINANT GRAIN SUPPORT WITH POSSIBLE LOCAL ASH MATRIX SUPPORT; >90% QUARTZ, SECONDARY CHERT TRACES OF ARGILLITE; FAIR TO GOOD POROSITY AND PERMEABILITY; GRADING TO PINKISH GRAY POOR INDURATED ASHY SILTS VERY COLLOIDAL TO ASHY TEXTURES; VERY HYDROPHILIC WITH A >50% ASH CONTENT; SILTS >9280' BECOMING INFUSED WITH CARBON GIVING A PALE YELLOW BROWN TO PALE BROWN HUE. Olson Creek #2 31 COAL/CARBONACEOUS CLAY + SHALE (9295'- 9375') = BLACK MOTTLED GRAYISH BLACK TO YELLOWISH BROWN TO BROWNISH BLACK NEAR CONTACTS; FIRM TO HARD; RESINOUS MOTTLED EARTHY LUSTER IN CLAY; HACKLY FRACTURE; SCATTERED THIN BEDS; VISIBLE BLEEDS GAS. TUFFACEOUS SANDSTONE/SAND (9375'-9405') = VERY LIGHT GRAY TO PINKISH GRAY; CLAST SIZE FINE LOWER TO VERY FINE LOWER; SUB ROUND; MODERATE TO WELL DEVELOPED SPHERICITY; MODERATE TO POOR SORTING; IMPACT TEXTURE; SUBMATURE TO MATURE NATURE; VARIOUS DEGREES OF TERRIGENOUS COMPONENTS; BOTH ASH/SILT (ABUNDANT) TO ARENACEOUS GRAIN SUPPORTED SAND IN THIN BEDDING; POOR TO GOOD POROSITY AND PERMEABILITY; NO OIL INDICATORS. TUFFACEOUS SILTSTONE (9420'-9450') = LIGHT GRAY; BROWNISH HUES; SOFT; MASSIVE TO SLI PLATY CUTTINGS; POORLY INDURATED; CLAYEY TO SILTY TEXTURE; SME SCATTERED CARBONACEOUS MATERIAL; DULL EARTHY LUSTER; MINOR LOOSE WHITE ASH IN SAMPLE TRAYS; INTERBEDDED WITH ASH AND THIN LOW GRADE COALS. CONGLOMERATIC SANDSTONE (9450'-9510') = ABUNDANT LOOSE GRAINS; COARSE TO UPPER FINE GRAINED; SME BROKEN FRAGMENTS; ANGULAR TO SUBANGULAR; POORLY SORTED; SME LITHIC FRAGMENTS; TRACE BROKEN CHERT LOW SPHERICITY; MINOR AMOUNT OF WHITE GRAY SILT/ASH MATRIX MATERIAL; SOME JASPER; TRACE LIGHT GREEN GRAINS; SLIGHT GAS INCREASE OVER INTERVAL CONGLOMERATIC SANDSTONE/TUFFACEOUS SANDSTONE (9510'-9570') = DOMINANTLY LOOSE GRAINS; CLEAR TO TRANSLUCENT TO WHITE GRAINS; LOWER COARSE TO UPPER FINE GRAINED; DOMINANTLY ANGULAR TO SUBANGULAR; LOW SPHERICITY; POORLY SORTED; TRACE JASPER; TRACE LITHIC GRS; MINOR AMOUNT OF WHITE/LIGHT GRAY SILT/ASH MATRIX MATERIAL PRESERVED; ONLY SLIGHT INCREASE IN GAS OVER INTERVAL. COAL (9570-9610') = BLACK; MOD HARD; BLOCKY TO PLATY CUTTINGS; CONCHOIDAL TO BLOCKY FRACTURE; SMOOTH TEXTURE; VITREOUS LUSTER; SME DARK GRAY CARBON SHALE; MULTIPLE BEDS; SOME VISIBLE BLEEDING GAS AT THE 9610' SAMPLE; ASSOCIATED WITH MULTIPLE GAS SHOWS; MAXIMUM GAS 902 UNITS @ 9610'. SAND/TUFFACEOUS SANDSTONE (9630'-9660') = DOMINANTLY LOOSE GRAINS; CLEAR TO WHITE TO TRANSLUCENT GRAINS; UPPER FINE TO LOWER MEDIUM GRAINS; SME LOOSE UPPER MEDIUM GRAINS; ANGULAR TO SUBANGULAR; MOD WELL SORTED; LOW SPHERICITY; SME PRESERVED LIGHT GRAY WITH BROWNISH HUES FROM MUD IN TRAYS; ASH/SILT MATRIX; TRACE MATRIX SUPPORTED SPECIMENS; TRACE LOOSE JASPER, LIGHT GREEN BROKEN GRAINS; EXHIBITED A 60 UNIT GAS INCREASE OVER BACKGROUND; NO SAMPLE SHOWS. TUFFACEOUS SILTSTONE (9660'-9720') = LIGHT GRAY WITH BROWNISH HUES FROM MUD; SOFT TO MUSHY; POORLY INDURATED; MASSIVE CUTTINGS; EARTHY TO IRREGULAR FRACTURE; SILTY TO CLAYEY TEXTURE; SOME THIN BLACK CARBONACEOUS LAMINATIONS; INTERBEDDED WITH THIN COALS AND CARBONACEOUS SHALES WITH MINOR GAS INCREASES FROM THESE THIN CARBONACEOUS INTERVALS. TUFFACEOUS SILTSTONE (9720'-9780') = LIGHT GRAY WITH BROWNISH HUES FROM MUD; SOFT; POORLY INDURATED; MASSIVE TO SLIGHT NODULAR CUTTING FROM TRANSPORT; CLAYEY TO SILTY TEXTURE; DULL EARTHY LUSTER; VERY FINE CARBONACEOUS MATERIAL; SOME LOOSE WHITE ASH IN SAMPLE TRAYS; SOME THIN LAMINATIONS; VARIABLE AMTS OF SILT; THINLY INTERBEDDED WITH CARBONACEOUS SHALE AND THIN COALS. Olson Creek #2 32 TUFFACEOUS SILTSTONE (9780'-9875') = OFF WHITE TO VERY PALE ORANGE GRADING TO LIGHT GRAY TO VERY LIGHT GRAY AFTER 9840’; POOR INDURATION; BRITTLE; NON TO VERY SLIGHT COHESIVE; SLIGHT ADHESIVE; EARTHY FRACTURE; SUB NODULAR HABIT FROM WELL BORE EROSIONAL TRANSPORT; MODERATE TO BRIGHT EARTHY LUSTER DECREASING WITH DEPTH; ASHY TO SILTY TEXTURE; MASSIVE GRADATIONAL TUFFACEOUS SILT; COMPOSED OF SILT, DEVITRIFIED ASH, VERY FINE SAND AND CARBON FINES WITH TRACE VARIOUS DETRITAL MATERIAL. COAL (9875'-9905') = BLACK SOME MOTTLED BROWNISH GRAY TO BROWNISH BLACK NEAR CONTACTS; FIRM TO HARD; RESINOUS SOME MOTTLED EARTHY LUSTER; MATTE TEXTURE; HACKLY TO SUB CONCHODIAL TO SUB PLANAR. TUFFACEOUS SANDSTONE/SAND/ASH (9905'- 9985') = VERY LIGHT GRAY TO VERY PALE ORANGE-PINKISH GRAY (ASH HUES); CLAST SIZE MEDIUM LOWER TO FINE LOWER; SUB ANGULAR TO SUB ROUND; MODERATE DEVELOPED SPHERICITY; MODERATE TO POOR SORTING; IMPACT TEXTURE; IMMATURE - MATURE NATURE UNCONSOLIDATED TO INTERBEDDED SANDS; HETROGENEOUS BEDDING; CLEAN SAND TO INTERBEDDED IN ABUNDANY ASH/SILT MATRIX; BOTH GRAIN AND MATRIX SUPPORTED; COMPOSED OF >90% QUARTZ, SECONDARY CHERT TRACE SILICEOUS MUDSTONE; POOR TO GOOD POROSITY AND PERMEABILITY; NO OIL. TUFFACEOUS SILTSTONE (10020'-10050') = LIGHT GRAY; BROWNISH HUES FROM MUD; SOME WHITE/PINK HUES FROM ASH; SOFT; MASSIVE TO SLIGHTLY PLATY; EARTHY TO IRREGULAR FRACTURE; SMOOTH TO SILTY TEXTURE; THIN LAMINATIONS; THIN CARB LAMINATIONS; SOME WHITE ASH LAMINATIONS; SOME LOWER TO UPPER FINE GRAINED TUFFACEOUS SANDSTONE EXAMPLES; SOME BLACK CARBONACEOUS SHALE SPECIMENS. TUFFACEOUS SILTSTONE (10050'-10080') = LIGHT GRAY; BROWNISH HUES FROM MUD; SOFT; POORLY INDURATED; MASSIVE TO SLIGHT PLATY CUTTINGS; IRREGULAR FRACTURE; NON CALCAREOUS; CLAYEY TO SILTY TEXTURE; VARIABLE AMTS OF SILT; GRADING TO TUFFACEOUS CLAYSTONE; INTERBEDDED WITH HARD, CARBONACEOUS SHALE. COAL (10090'-10100') = BLACK; MOD HARD; FLAKY TO BLOCKY CUTTINGS; SMOOTH TEXTURE RESINOUS TO VITREOUS LUSTER IN HIGH GRADE COAL SPECIMENS; BLOCKY FRACTURE; SOME DARK GRAY, CARBONACEOUS SHALE SPECIMENS; ASSOCIATED WITH 151 UNIT GAS SHOW. TUFFACEOUS SANDSTONE (10110'-10140') = DOMINANTLY LOOSE GRAINS; LOWER FINE TO LOWER MEDIUM GRAINS; TRACE WHITE MATRIX IN SAMPLE TRAYS; ANGULAR TO SUBANGULAR; LOW SPHERICITY; TRACE REDDISH AND GREENISH GRAINS; TRACE CARBONACEOUS MATERIAL; POORLY REPRESENTED IN SAMPLES AS MAINLY DISINTERGRATES TO LOOSE QUARTZ IN SAMPLE TRAYS; NO HYDROCARBON SHOWS. TUFFACEOUS SILTSTONE (10200'-10230') = LIGHT GRAY; BROWNISH HUES FROM MUD; SOFT; SLIGHTLY PLATY CUTTINGS; IRREGULAR FRACTURE; SILTY TEXTURE; DULL EARTHY LUSTER; VERY FINE LAMINATIONS; WHITE ASH LAMINATIONS; ABUNDANT ASH IN SAMPLE TRAYS; INTERBEDDED WITH THIN COALS. TUFFACEOUS SILTSTONE (10230'-10280') = VERY LIGHT GRAY; WHITE GRAY; BROWNISH HUES FROM MUD; SOFT SLIGHTLY PLATY CUTTINGS; EARTHY TO IRREGULAR FRACTURE; CLAYEY TO SILTY TEXTURE; SME WHITE ASH LAMINATIONS ASH/SILTSTONE (10280'- 10320') = OFF WHITE TO PINKISH GRAY; TUFFACEOUS SILT INTERBEDDED WITH DEVITRIFIED ASH AND LOCAL TUFFITE; POORLY INDURATED; EARTHY Olson Creek #2 33 LUSTER; ASHY TO SILTY TEXTURE; APPEARS REWORKED AND REDEPOSITED; GRADING TO ASHY TUFFACEOUS SILTSTONE AND MINOR BEDS OF VERY FINE GRAIN TUFFACEOUS SANDSTONE; COMPOSED OF 40% ASH, 40% SILT, 20% VERY FINE SAND, CARBON FINES AND PYROCLASTIC SHARDS; NO DISCERNABLE BEDDING OR SEPARATION POINTS. TUFFACEOUS SILTSTONE (10320'-10400') = PINKISH GRAY; POOR INDURATION; BRITTLE; SLIGHT COHESIVENESS; SL ADHESIVENESS; EARTHY FRACTURE; SUB NODULAR HABIT FROM WELL BORE EROSIONAL TRANSPORT; EARTHY LUSTER; ASHY TO SILTY TEXTURE; MASSIVE GRADATIONAL TUFFACEOUS SILT; BECOMING ASHY IN PARTS TO INTERBEDDED VERY FINE GRAIN SAND; SMALL COAL BEDS AND THIN CARBONACEOUS SHALE AND CLAY. COAL/CARBONACEOUS SHALE (THIN BEDS) = (10400'-10440') =BLACK; FIRM TO HARD; RESINOUS LUSTER TO EARTHY NEAR CONTACTS; MATTE TEXTURE; HACKLY TO BLOCKY TO SUB CONCHOIDAL FRACTURES; VISIBLE BLEEDING GAS FROM TRUE COAL CUTTINGS. TUFFACEOUS SILTSTONE (10440-10470') = LIGHT GRAY; SOFT; PLATY CUTTINGS; IRREGULAR FRACTURE SILTY TEXTURE; SCATTERED CARBONACEOUS MATERIAL; INTERBEDDED WITH THIN COALEY BEDS. CONGLOMERATIC SANDSTONE (10470'-10500') = WHITE TO GRAY WHITE; POORLY PRESERVED; LOOSE UPPER COARSE GRAINS; FINE TO UPPER COARSE GRAINED; ANGULAR TO SUBANGULAR; POORLY SORTED; LOW SPHERICITY; ASH MATRIX; ABUNDANT WHITE ASH IN SAMPLE TRAYS; MATRIX TO GRAIN SUPPORTED; TRACE LITHIC FRAGMENTS; NO SAMPLE SHOWS. TUFFACEOUS SANDSTONE (10500'-10530') = WHITE TO LIGHT GRAY WHITE; SOFT; LOWER TO UPPER FINE GRAINED; ANGULAR TO SUBANGULAR; MOD SORTED; LOW SPHERICITY; ASH/SILT MATRIX; ABUNDANT LOOSE ASH IN SAMPLE TRAYS; GRADING TO TUFFACEOUS SILTSTONE; THIN CARBONACEOUS LAMINATIONS NO SAMPLE SHOWS. TUFFACEOUS SILTSTONE (10530'-10590') = LIGHT GRAY WITH BROWNISH HUES FROM MUD; SOFT; DULL EARTHY LUSTER; CLAYEY TO SILTY TEXTURE; VERY THIN CARBONACEOUS LAMINATIONS; SLI PLATY CUTTINGS; IRREGULAR FRACTURE; INTERBEDDED WITH THIN CARB INTERVALS WHICH PRODUCE MINOR GAS. TUFFACEOUS SANDSTONE/TUFF (10590'-10520') = WHITE TO WHITE/GRAY; SME BROWNISH HUES FROM MUD; SOFT; LOWER VERY FINE TO UPPER FINE GRAINED; LOW SPHERICITY; ANGULAR TO SUBANGULAR; MOD WELL SORTED; DOMINANTLY ASH MATRIX; ABUNDANT LOOSE WHITE ASH IN SAMPLE TRAYS; MATRIX SUPPORTED; SME SCATTERED CARBONACEOUS MATERIAL; GRADING TO TUFFACEOUS SILTSTONE. TUFFACEOUS SILTSTONE (10520'-10700') = VERY LIGHT GRAY; SME MEDIUM LIGHT GRAY; BROWNISH HUES FROM MUD; SOFT; SLIGHT PLATY TO OCC FLAKY CUTTINGS; IRREGULAR FRACTURE; SILTY TO CLAYEY TEXTURE; VERY FINE CARBONACEOUS LAMINATIONS; SOME LOOSE WHITE ASH IN SAMPLE TRAYS; DULL EARTHY LUSTER; SME CARBONACEOUS SHALE BOUNDARIES INDICATING INTERBEDDING WITH CARBONACEOUS SHALE. CARBONACEOUS SHALE AND CLAY/COAL (10700-10770') = BROWNISH GRAY TO PALE BROWN IN CARBON CLAY TO BLACK IN BITUMINOUS COAL; BRITTLE IN CARBON CLAY TO HARD IN COAL; EARTHY TO DISTINCT RESINOUS LUSTER; SILT TO ASHY CARBON CLAY TEXTURE TO MATTE IN COAL; SUBPLANAR FRACTURE IN CARBON CLAY TO HACKLY IN COAL; VISIBLE BLEEDING GAS IN MOST COAL FRAGMENTS; OCCURS AS THIN COAL BEDS TO THICK CARBONACEOUS CLAY AND CARBONACEOUS SHALE. Olson Creek #2 34 TUFFACEOUS SILTSTONE (10770'-10850') = PALE BROWN TO VERY PALE ORANGE AND VARIOUS HUES OF BOTH COLORS; GRADATIONAL SILT AND VARIOUS DEGREES OF CARBON CLAY; POOR INDURATION NON TO SLIGHTLY COHESIVE SLIGHTLY ADHESIVE; EARTHY FRACTURE; SUB NODULAR TO SUB PLANAR HABIT; HYDROPHILIC EARTHY LUSTER + LIGHT CARBON APPEARANCE; ASHY TO SILTY TEXTURE; GRADATIONAL BEDS OF SILT AND CARBON CLAY/SILT; SOME MICRO LAMINAE OF BLACK CARBON SCATTERED. CONGLOMERATE SAND (THIN BEDS) (10850'-10920') = VERY LIGHT GRAY TO OFF WHITE; CLAST SIZE COARSE LOWER TO FINE UPPER; SUB ANGULAR TO SUB ROUND; MODERATE DEVELOPED SPHERICITY; POOR TO MODERATE SORTING; IMPACT TO SOME CHIP TEXTURE; SUB MATURE NATURE; UNCONSOLIDATED TO SCATTERED MODERATE CONSOLIDATED CLUSTERS; GRAIN SUPPORT TO SECONDARY MATRIX SUPPORT; TRACE EPIDOTE STAIN; ASH SCATTERED THROUGH OUT SAMPLE; COMPOSED OF PREDOMINANTLY QUARTZ, SECONDARY CHERT TRACE DARK LITHICS (VOLC?); POOR TO FAIR POROSITY AND PERMEABILITY; NSFOC. TUFFACEOUS SILTSTONE (10920'-10955') = PALE BROWN TO VERY PALE ORANGE AND VARIOUS HUES OF BOTH COLORS; GRADATIONAL SILT AND VARIOUS DEGREES OF CARBON CLAY; POOR INDURATION NON TO SLIGHTLY COHESIVE SLIGHTLY ADHESIVE; EARTHY FRACTURE; SUB NODULAR TO SUB PLANAR HABIT; HYDROPHILIC EARTHY LUSTER + LIGHT CARBON APPEARANCE; ASHY TO SILTY TEXTURE; GRADATIONAL BEDS. COAL (10960'-11020') = BLACK; MOD HARD; SPLINTERY TO FLAKY CUTTING; BLOCKY TO PLANAR FRACTURE; SMOOTH TEXTURE; SLIGHT RESINOUS TO VITREOUS LUSTER; TRACE BLEEDING GAS FROM SPECIMENS; ASSOCIATED WITH 196 AND 133 UNIT GAS SHOWS; INTERBEDDED WITH TUFFACEOUS SILTSTONES. CONGLOMERATIC SANDSTONE/TUFFACEOUS SANDSTONE (11020'-11040') = WHITE TO WHITE GRAY; SOFT; POORLY PRESERVED; UPPER COARSE TO UPPER FINE GRAINED; LOW SPHERICITY; POORLY SORTED; MATRIX SUPPORTED; TRACE CHERT; ABUNDANT LOOSE ASH MATRIX MATERIAL IN SAMPLE TRAYS. TUFFACEOUS SANDSTONE/CONGLOMERATIC SANDSTONE (11060'-11100') = WHITE TO LIGHT GRAYISH WHITE; SOFT; MINOR COARSE GRAINS; DOM LOWER FINE TO UPPER MEDIUM GRAINED; ANGULAR TO SUBANGULAR; LOW SPERICITY; DOM WHITE ASH MATRIX; MATRIX SUPPORTED; TRACE LITHIC FRAGMENTS; LIGHT GREEN GRAINS; TRACE JASPER; ABUNDANT ASH IN SAMPLE TRAYS; NO SIGNIFICANT GAS INCREASE OVER INTERVALS. TUFFACEOUS SILTSTONE (11100'-11130') = LIGHT GRAY; BROWNISH HUES FROM MUD; SOFT; MASSIVE TO SLI PLATY CUTTINGS; IRREGULAR FRACTURE; SILTY TEXTURE; ABUNDANT CARBONACEOUS LAMINATIONS AND SCATTERED CARBONACEOUS MATERIAL; INTERBEDDED WITH COALS. COAL (11150'-11170') = BLACK; MOD HARD; SPLINTERY TO BLOCKY CUTTINGS; RESINOUS TO VITREOUS LUSTER; BLOCKY TO PLANAR FRACTURE; VISIBLE BLEEDING GAS FROM SPECIMENS; SOME THIN DARK BROWN CARBONACEOUS SHALE INTERBEDS; ASSOCIATED WITH 205 UNIT GAS SHOW. TUFFACEOUS SILTSTONE/SANDSTONE (11170'-11230') = LIGHT GRAY WITH BROWN HUES; SOFT; IRREGULAR FRACTURE; MASSIVE; ABUNDANT LOOSE FINE TO MEDIUM QUARTZ GRAINS IN SAMPLE TRAYS; ABUNDANT WHITE ASH IN SAMPLE TRAYS; GRADATIONAL TO SANDSTONE; INTERBEDDED WITH THIN COALS WHICH PRODUCE 100+ GAS UNITS. Olson Creek #2 35 COAL/CARBONACEOUS SHALE (11230'-11285') = DOMINANT BLACK; SME DARK GRAY TO BROWN IN CARBONACEOUS SHALE SPECIMENS; MODERATELY HARD; FLAKY TO BLOCKY CUTTINGS; PLANAR TO BLOCKY FRACTURE; RESINOUS LUSTER IN CARBONACEOUS SHALE; VITREOUS LUSTER IN HIGH GRADE COAL; SOME BROWN SHALE LAMINATIONS IN COAL INDICATING THIN INTERBEDDING; ASSOCIATED WITH MULTIPLE GAS SHOWS RANGING FROM 103 TO 163 UNITS SAND/SANDSTONE/CONGLOMERATIC SANDSTONE (11320'-11400') = VERY LIGHT GRAY; CLAST SIZE COARSE UPPER TO MEDIUM LOWER; SUB ANGULAR TO SUB ROUND; SOME ANGULAR BIT IMPACTED COARSE GRAINS; MODERATE DEVELOPED SPHERICITY; MODERATE SORTING; BIMODAL WITH COARSE CONGLOMERATIC TO MEDIUM GRAIN MATRIX SAND; IMPACTED TO CHIP TEXTURE; SUB MATURE NATURE; UNCONSOLIDATED WITH SECONDARY MEDIUM GRAIN CONSOLIDATED SANDSTONE CLUSTERS; BOTH GRAIN AND MATRIX SUPPORTED; ASH MATRIX DECRESING WITH DEPTH AS WELL AS GRAIN SIZE; COMPOSED OF PREDOMINANTLY QUARTZ, SECONDARY CHERT; TRACE EPIDOTE, FELDSPAR, IGNEOUS AND CHLORITE; FAIR POROSITY; FAIR TO POOR PERMEABILITY; NO SHOW OF OIL FLUORESCENCE OR OIL CUTS. SAND (11400'-11460') = VERY LIGHT GRAY; CLAST SIZE PRIMARY COARSE LOWER TO FINE LOWER, SECONDARY COARSE UPPER TO VERY COARSE AND VERY FINE GRAINS; COARSE DECREASING WITH DEPTH; SUB ANGULAR TO SUB ROUND; SCATTERED ANGULAR COARSE BIT IMPACTED GRAINS; MODERATE TO POOR SORTED IMPACT TO CHIP (COARSE GRAIN) TEXTURE; SUB MATURE NATURE; PREDOMINANTLY UNCONSOLIDATED SECONDARY CLUSTERS OF FINE GRAIN SANDSTONE; BOTH GRAIN AND ASH SUPPORT; ASH HYDROPHILIC; COMPOSED OF PREDOMINANTLY QUARTZ, SECONDARY CHERT, TRACE EPIDOTE, CHLORITE, IGNEOUS, TUFF MUSCOVITE; FAIR POROSITY AND PERMEABILITY NO SHOW OF OIL FLUORSECENCE OR CUT. DEVITRIFIED TUFF AND ASH (11460'-11587') = CONTINUED SAND ABOVE WITH LIGHT GREENISH GRAY TO VERY LIGHT GRAY DEVITRIFIED TUFF PINKISH GRAY DEVITRIFIED ASH AS MATRIX OR INTERBEDDED; GLASS SHARDS NOT DISCERNABLE DUE TO DEVITRIFICATION GRADES TO TUFF IN PARTS; POOR TO MODERATE INDURATION; SATIN TO RESINOUS TO EARTHY LUSTER; SMOOTH TO ASHY TEXTURE. Olson Creek #2 36 3.4 SAMPLING PROGRAM AND DISTRIBUTION Set Type and Purpose Interval Frequency Distribution 1 Cleaned and Spun Dry 150’ – 11589’ 30’ 10’-(through gas shows) Cook Inlet Energy Attn: Art Saltmarsh 601 W. 5th Ave, Suite 310 Anchorage, AK 99501 2 Cleaned and Spun Dry 150’ – 11589’ 30’ 10’-(through gas shows) AOGCC Attention: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, AK 99515 Olson Creek #2 37 4 DRILLING DATA 4.1 DAILY ACTIVITY SUMMARY 8/28/2014: Rig repair - troubleshoot and repair foot throttle on rig floor. Pick up collar slips and clamps. Calibrate Halliburton's encoder. Pick up 3 joints of 8" flex collars. Pressure test mud pumps and lines to 3500 psi. Hold a pre job safety meeting for picking up tools. Pick up mud motor and adjust to 1.5 pick up tools and MWD tool. Drill out conductor pipe to 117'. Drill formation from 117' to 249'. Rack back two stands of HWDP and pick up 8" flex collars and jars. Trip gas was zero. Drill formation from 249' to 405'. Wait on BOS to fix grinder. Lay out and strap drill pipe and pick up drill pipe. 8/29/2014: Finish working on boss grinder. Drill from 404' to 1000' @ 650 gpm, 1350 psi. Circulate and wait on Boss unit. Drill/slide from 1000' to 1202'. Lube top drive, draw tool and crown. Drill/slide from 1202' to 1581'. Possum belly and shakers packed off with cuttings, clean possum belly and shakers and work the drill pipe at midnight. 8/30/2014: Continue to clean out the possum belly and flow line of packed off cuttings. Drill from 1581' to 2023' (casing point). Circulate bottoms up twice and back ream out of the hole to 220' at 650 gpm/60 rpm. Trip in the hole from 220' to 2023'. Work tight spots at 1870' (coal). Circulate bottom's up twice at 2023'. Wiper gas was 7 units. Observe a 15 minute flow check and pump a 20 bbl/1.5 over sweep. Trip out of the hole on elevators from 2023' to BHA. Work the BHA and lay down the directional tools. Drain the motor and brake the bit. Clean the rig floor and lay down unwanted tools from the rig floor. Pick up centralizers and ready the rig floor for the casing run. Hold a pre job safety meeting and rig up the casing tools. 8/31/2014: Finish rigging up casing tools. Run baker lock float and shoe track. Run 9 5/8" casing to 2023'. Circulate 8 b/m at 130 psi. Trip gas was three units. Rig up cement head. Hold a pre job safety meeting concerning cementing. Cement the casing and wait on the cement. No losses while circulating and no losses during the cement job. Nipple down the diverter line, annular knife valve, DSA and cut the casing. 9/1/2014: Finish rigging up casing tools. Run baker lock float and shoe track. Run 9 5/8" casing to 2023'. Circulate 8 b/m at 130 psi. Trip gas was three units. Rig up cement head. Hold a pre job safety meeting concerning cementing. Cement the casing and wait on the cement. No losses while circulating and no losses during the cement job. Nipple down the diverter line, annular knife valve, DSA and cut the casing. 9/2/2014: Nipple down riser, DSA, knife valve, annular and dresser sleeve. Cut casing at the conductor and casing weld on the well head. Prep casing and conductor and well head on. Clean the mud pits. Nipple up the choke line. Set the lower rams, blind rams and upper pipes. Choke HCR and manual. Kill HCR and manual and set annular. 9/3/2014: Change lower rams to 2 7/8 x 5 UBR. Nipple up riser and flow line. Rig up cat walk and beaver slide. Rig up test unit. Build mud in pits. Hold a pre job safety meeting on testing BOPE. Start testing the BOPE. 9/4/2014: Finish testing the bop equipment. Make up the BHA to 888'. Trip in the hole with singles from the catwalk from 888' to 1927'. Lube the rig; draw works, crown and top drive. Trip in the hole to 1960'. Rig up the test pump to the choke. Hold a pre job safety meeting. Test the casing to 3000 psi for 30 minutes. Rig down the test pump and drill out the float equipment and 20' of new hole. Displace the spud mud. Hold a pre job safety meeting and run a F.I.T. to 15 ppg EMW. Rack back 2 stands of drill pipe and load the pipe rack and strap the new pipe. Pick up drill pipe and rack back in the derrick. Drill formation from 2045' to 2216' (midnight). Olson Creek #2 38 9/5/2014: Drill formation from 2216' to 2596'. Circulate and condition the hole while changing out the swab on mud pump #2. Drill from 2596' to 3260'. Back ream 2 stands and wiper trip on elevators from 3072' to 1948'. Pick up Drill pipe and trip in the hole from 1948' to 3260'. Wiper gas was 11 units. Proper fill on trip. Slight over pull at 2772' (coal). Drill from 3260' to 3641' (midnight). 9/6/2014: Drill/slide formation to 4637'. Circulate bottoms up and wiper trip on elevators from 4637' to 3180'. Pick up drill pipe from 3277' to 4637'. Trip was slick (no pull).wiper gas was 24 units. Drill/slide formation from 4637' to 4879. 9/7/2014: Drill and slide formation from 4879' to 5734'. Circulate bottoms up to replace the swab on mud pump #2. Lube and service the rig, drill/slide from 5734' to 5018'. Circulate bottoms up and flow check. Wiper trip from 6019' to 5365'. Circulate bottom's up @ 5365' (to clean the hole) with a maximum gas kick of 23 units. 9/8/2014: Circulate bottoms up at 4660' (during wiper trip). Pick up drill pipe from 4729' to 5275'. Lay out drill pipe and strap 21 joints of drill pipe. Pick up and run in the hole from 5275' to 5928'. Wash down one stand to bottom. Drill/slide from 6019' to 6212'. Trouble shoot pressure loss. Drill/slide from 6212' to 6403'. Circulate and pump suction and discharge screens for debris. Drill/slide from 6403' to 6821' (midnight). 9/9/2014: Drill/slide formation from 6821' to 7290'. Circulate the hole and work on mud pump #2. Drill/slide formation from 7290' to 7543'. Circulate and take a survey. Pump a high viscosity sweep and start to pull out of the hole on elevators from 7343. Hole pulled tight at 4455'. Worked the pipe and circulated bottoms up and continued to pull out of the hole to test bop equipment. 9/10/2014: Trip out of the hole from 4455' to 2023'. Circulate bottoms up and flow check the well. Trip out of the hole from 2023' to 888'. Work the BHA and rack back the drill collars. Hold a pre job safety meeting foe MWD tools. Down load the tool. Lay out the directional tools. Break out the bit (no balling noted) and rack back the collars. Clean the rig floor and blow down the kelly. Pull the wear bushing and rig up the test pump. Drain and flush the stack. Hold a pre job safety meeting on testing the BOPE and test the BOPE. Rig down the test equipment and blow the choke manifold and set the wear bushing. Lube the crown, draw works and top drive. Check a leak on the top drive and wait on tools. Clean the rig floor. Make up new BHA and strap the new BHA. Hold a pre job safety meeting on picking up the BHA. Run in the hole with Tapper mill to 2680' - 1865' and work the shoe area at 43 rpm, 34779 torque, and 482 pp @ 447 gpm (midnight). 9/11/2014: Very little metal in samples during milling run. Trip out of the hole from 2693' to BHA (888'). Lay down the BHA and clean the rig floor. Line out new BHA (RR bit #2). Hold a pre job safety meeting with DD and MWD supporting roles to handle the BHA. Upload the MWD tools and hold a pre job safety meeting on loading sources and load sources. Trip in the hole from BHA to 2000'. Circulate bottoms up twice at the shoe. Trip in the hole from 2000' to 4175'. Tight area increase of psi on the drill pipe. Flow check: shut in the well and circulate on the choke at slow pump rate for bottoms up open choke and annular with no flow (static). Run in hole on elevators to tight zones of 5921' and 6871'. Ream to bottom from 6900' to 7543'. Trip gas was 1170 units (from migrating up hole coal gas from 7310'). Drill/slide from 7543' to 7733' (midnight). 9/12/2014: Drill/slide from 7733' to 8305'. Service the rig, grease top drive, blocks and draw works. Drill/slide from 8305' to 8480'. Circulate bottoms up to circulate out samples. Samples indicate 100% tuffaceous siltstone. Pump a high viscosity sweep around and prep to wiper trip to the shoe. 9/13/2014: Circulate bottoms up at 8480'. Pull out of the hole to 2080'. Circulate bottoms up three times at 550 gpm. Maximum gas was 165 units. Conduct a trip drill and hold a pre job safety meeting on the Olson Creek #2 39 same. Cut and slip 60' of drill line and service the rig. Re-spool drill line, fix wraps and calibrate the same. Trip in the hole on elevators from 2023' to 8480' and washing as needed. Wiper gas was 483 units showing some gas migration. 8' of fill noted on bottom. Pump a high viscosity sweep and circulate bottoms up three times at 500 gpm to clean the hole. 9/14/2014: Circulate hole at 8480' (td) and flow check the well. Pull out of the hole from 8480' to 7830'. Pump a 15 bbl dry job and trip out of the hole to 2100'. Circulate bottoms up four times at 550 gpm and pump a 15 bbl dry job. Maximum gas was 24 units. Trip out of the hole from 2100' to 440'. Lay down the jars and stand back the HWDP. Lay down the collars and hold a pre job safety meeting on nuke sources. Remove the nuke sources and down load the MWD tools. Lay down the MWD, motor and BHA. Pick up the 7" test joint and 8' pup joint. Pull the wear bushing and set the test plug. Pull the wear ring and set the test plug. Change out the upper rams to 7". Fill the stack and test the upper rams and Hydril to 250 low and 3000 high. Rig down the test joint and test pump. Service the rig and remove elevators and bails from the top drive for the CRT. Rig up the casing equipment and pick up the CRT with the blocks. Rig up the CRT to the top drive. Pick up the power tongs and hold a pre job safety meeting on running the casing. Make up the shoe and floats and run in the hole to 128' to check the floats. Prep to run casing. 9/15/2014: Run 7" casing at 25 fpm to 300'. Change out power tongs due to not reading torque. Run casing from 300' to 2010' filling every joint on the run. Circulate bottoms up at 2012' @ 2.5 b/m. Maximum gas was 10 units. Run 7" casing from 2012' to 8450' filling pipe on the run. Circulate casing at 8450' at 188 gpm. Maximum trip gas was 128 units (Building spacer for cement job). Tag bottom and circulate. Lay down a pup and single and pick up landing joint. 9/16/2104: Circulate at 5 BPM to clean up the hole at 8480' while rigging up for cement job. Cement hole as per program and lay down the landing joint. Wash down stack and drain. Empty the cellar and verify the top of the hanger is clear. Land pack off on top of the hanger. Test void to 5000 psi for ten minutes. Lay down the casing CRT, service loop, and tongs. Prep floor and pick up thread protectors for laying down the drill pipe. Lay down 5" Drill pipe and lay down HWDP (7 stands). Service the rig and prep floor for changing 7" rams and testing BOPE. 9/17/2014: Lay down 5" tools and pick up 4" tools. Test subs and saver subs and start cleaning out the mud tanks. Change out 5" saver sub, grabber box and stabilizer guide. Build test assembly and r/I hole. Change out 7" casing rams to 2 7/8 x 5" pipe rams. Pull and reinstall mouse hole and service choke valve. Flush the stack, top drive and choke Lines for bop testing. Pressure up on new test pump to ensure no leaks. Test the bop equipment. Change out saver sub, die blocks and stabbing guide. Rig up for testing IBOP’s and test the same. Rig down the test Equipment and prep to pick up 4000' of drill pipe and rack back in the derrick. 9/18/2014; Pick up and strap 4" drill pipe to 4141' and run in the hole. Install stripping rubbers, clean the rig floor and rack back 44 stands of drill pipe. Service the rig and bring tools to the rig floor. Change out the elevators and hold a pre job safety meeting on making up the BHA. Make up the BHA and down load the Halliburton tools. Hold a pre job safety meeting with Halliburton on loading the sources and load the same. Pick up the BHA and flex collars. Change out the elevators and pick up the HWDP, jars and cross overs. Pick up 4000' of drill pipe. 9/19/2014: Pick up 4" drill pipe from 5489' to 8391'. Service the rig and wash down from 8286' and tag cement at 8392'. Pump a full circulation with 9.4 ppg mud at 200 gpm and 10 rpm. Hold a pre job safety meeting on the casing test and test the casing to 5000 psi = good test. Drill out plugs, float collar and shoe track from 8392' to 8476'. Tag the shoe at 8476'. Drill 20' of new hole from 8460' to 8500'. Trip gas was 4 units. Circulate bottoms up to clean the hole for the F.I.T. perform the F.I.T to 3000 17.1 EMW = good test. Drill and slide from 8500' to 8763' at midnight. Olson Creek #2 40 9/20/2014: Drill/slide to 8911'. Circulate bottoms up and pull out of the hole from 8911' to 4300'. Secure the well and trouble shoot inertia brake. Cool off inertia brake and shut off the air supply to damaged inertia brake. Pull out of the hole from 4300' to 1634' and service the rig and wait on peak to deliver agitator. Pick up agitator and cross over's and test the agitator. The agitator is weak. Lay down and pick up new string agitator and retest at 240 gpm. Trip in the hole from 1634' to 5320' at midnight. 9/21/2014: Trip in the hole from 5320' to 8911' td (wash down the last two stands. Wiper gas was 51 units. Drill/slide from 8911' to 9337' (midnight). 9/22/2014: Drill/slide formation from 9337' to 9814'. Circulate bottoms up for wiper trip. Pull out of the hole from 9814' to 8475'. Service the rig and trip in the hole to 9814'. Wiper gas was 331 units. Drill/slide from 9814' to 9880' (midnight). 9/23/2014: Drill/slide from 9880' to 10414'. 9/24/2014: Drill formation from 10414' to 10514'. Work on mud pumps #1 and #2. Drill slide from 10514' to 10703'. Service the rig. Drill from 10703' to 10849' (midnight). 9/25/2014: Drill formation from 10849' to 11504'. 9/26/2014: Drill formation from 11504' to 11589' (td). Circulate the hole clean at 270 gpm and 2936 psi. Trip out of the hole from 11589' to 9101'. Pump out from 9101' to 8475'. Circulate bottoms up twice at the shoe and flow check the well. Pump a 20 bbl dry job and trip out of the hole on elevators from 8445' to the BHA. Lay down the string agitator and work the BHA out and jars plus 2 joints of HWDP. Hold a pre job safety meeting on pulling the sources. Pull the sources and start to down load the MWD tool at midnight. 9/27/2014: Lay down the BHA assembly. Clean the rig floor and rig up the test plug. Pull the wear bushing. Hold a pre job safety meeting for testing BOPE. Flush the stack and set the test plug and fill the stack with water. Begin testing the BOPER. Finish testing the BOPE and rig down the test pump and pull the test plug and set the wear bushing. Hold a pre job safety meeting about picking up running tools and pick up the running tools and plug. Trip in the hole to 8410'. Set packer and unsting out and circulate bottoms up at 1912 strokes at 30 spm at 526 psi. Hold a pre job safety meeting on cementing hook ups. Test cement back side to 3000 psi for 15 minutes (Midnight). Olson Creek #2 41 4.2 SURVEY DATA Measured Depth (ft) Inclination ( deg) Azimuth ( deg ) TVD ( ft ) +NS- ( ft ) +EW- ( ft ) Vertical Section ( ft ) DLS (deg/100 ft ) 26.9 0 0 26.9 0 0 0 0 192.57 0.3 244.13 192.57 -0.19 -0.39 0.35 0.18 225.57 0.43 333.07 225.57 -0.12 -0.53 0.5 1.57 312.07 0.36 12.91 312.07 0.44 -0.61 0.68 0.32 400.84 0.3 3.47 400.84 0.94 -0.54 0.69 0.09 491.46 1.9 286.38 491.44 1.6 -1.96 2.2 2.05 580.42 3.85 281.57 580.28 2.61 -6.31 6.66 2.21 670.98 6.56 280.24 670.46 4.14 -14.38 14.87 2.99 759.47 9.12 280.53 758.12 6.33 -26.25 26.94 2.9 854.00 14.3 281.01 850.64 9.93 -45.09 46.12 5.48 951.98 15.84 280.95 945.25 14.78 -70.11 71.59 1.57 1048.58 18.99 280.03 1037.42 20.03 -98.53 100.50 3.27 1143.78 23.69 279.27 1126.06 25.81 -132.68 135.13 4.94 1239.16 27.01 279.81 1212.24 32.59 -172.94 175.96 3.49 1334.74 31.83 280.14 1295.47 40.73 -219.17 222.9 5.05 1430.18 35.62 278.8 1374.84 49.41 -271.43 275.87 4.05 1523.89 39.72 278.57 1449.00 58.06 -328.03 333.12 4.37 1619.13 43.93 280.07 1519.95 68.37 -390.68 396.61 4.55 1714.72 47.37 278.39 1586.77 79.3 -458.14 464.95 3.81 1809.03 47.58 278.06 1650.51 89.25 -526.93 534.43 0.34 1904.2 49.80 278.31 1713.33 99.42 -597.68 605.89 2.34 1963.94 49.43 278.11 1752.04 105.92 -642.72 651.38 0.68 2049.07 49.51 277.95 1807.36 114.96 -706.79 716.05 0.17 2076.55 49.05 278.53 1825.29 117.95 -727.4 736.87 2.32 2171.3 46.34 277.67 1889.06 127.83 -796.77 806.91 2.94 2267.1 44.25 279.64 1956.45 138.05 -864.07 874.98 2.63 2364.13 41.44 279.84 2027.59 149.21 -929.1 940.96 2.90 2458.47 40.91 279.73 2098.60 159.77 -990.3 1003.07 0.57 2556.54 39.14 279.55 2173.69 170.33 -1052.48 1066.13 1.81 2647.34 38.33 278.85 2244.52 179.41 -1108.56 1122.94 1.02 2742.36 38.06 278.75 2319.2 188.4 -1166.63 1181.69 0.28 2838.63 36.78 279.10 2395.65 197.47 -1224.42 1240.19 1.35 2932.82 36.61 278.94 2471.18 206.29 -1280.01 1296.47 0.22 3026.09 36.02 278.27 2546.33 214.56 -1334.61 1351.69 0.76 3120.25 35.9 278.37 2622.54 222.56 -1389.32 1406.96 0.13 3218.51 35.75 278.14 2702.21 230.82 -1446.25 1464.46 0.21 3313.09 36.14 278.35 2778.78 238.78 -1501.2 1519.97 0.43 3407.57 37.08 278.71 2854.62 247.15 -1556.91 1576.3 1.02 3502.35 37.08 279.33 2930.24 256.11 -1613.35 1633.44 0.39 3597.94 37.96 280.49 3006.06 266.13 -1670.70 1691.66 1.18 Olson Creek #2 42 Measured Depth (ft) Inclination ( deg) Azimuth ( deg ) TVD ( ft ) +NS- ( ft ) +EW- ( ft ) Vertical Section ( ft ) DLS (deg/100 ft ) 3693.20 37.54 280.33 3081.38 276.67 -1728.06 1749.97 0.45 3788.13 37.45 280.36 3156.69 287.05 -1784.91 1807.76 0.10 3882.97 37.55 280.41 3231.93 297.45 -1841.70 1865.49 0.11 3978.37 38.34 280.74 3307.16 308.22 -1899.36 1924.14 0.85 4073.38 38.05 279.53 3381.83 318.56 -1957.19 1982.89 0.84 4164.93 38.44 280.72 3453.73 328.53 -2012.98 2039.55 0.91 4260.45 38.34 281.40 3528.61 339.91 -2071.19 2098.86 0.45 4354.93 38.29 281.29 3602.73 351.43 -2128.62 2157.40 0.09 4448.85 39.01 281.33 3676.09 362.94 -2186.14 2216.04 0.77 4545.52 38.95 281.39 3751.24 374.91 -2245.75 2276.82 0.08 4645.29 38.85 281.01 3828.89 387.09 -2307.21 2339.44 0.26 4740.90 38.88 280.85 3903.33 398.46 -2366.11 2399.43 0.11 4836.23 38.74 280.38 3977.61 409.47 -2424.84 2459.16 0.35 4931.54 38.85 279.60 4051.90 419.83 -2483.65 2518.88 0.53 5026.46 38.50 279.74 4126.00 429.79 -2542.12 2578.2 0.38 5121.58 38.54 279.39 4200.42 439.63 -2600.54 2637.43 0.23 5216.7 38.16 279.61 4275.02 449.37 -2658.74 2696.45 0.42 5310.33 38.18 279.93 4348.64 459.19 -2715.77 2754.31 0.22 5404.91 38.24 278.35 4422.96 468.48 -2773.52 2812.8 1.04 5501.96 37.80 278.43 4499.41 477.2 -2832.65 2872.56 0.45 5596.16 38.53 278.39 4573.47 485.71 -2890.24 2930.75 0.77 5691.28 38.38 279.09 4647.96 494.7 -2948.7 2989.90 0.49 5784.41 38.14 279.11 4721.09 503.82 -3005.65 3047.57 0.27 5880.95 38.38 278.82 4796.90 513.14 -3064.69 3107.34 0.32 5979.71 37.94 279.27 4874.55 522.73 -3124.96 3168.36 0.53 6073.62 37.47 279.12 4948.85 531.9 -3181.65 3225.79 0.51 6168.03 37.58 279.94 5023.73 541.42 -3238.36 3283.29 0.54 6263.28 36.95 279.48 5099.53 551.15 -3295.2 3340.96 0.73 6359.76 37.45 279.93 5176.38 560.99 -3352.7 3399.29 0.6 6455.27 37.45 281.26 5252.21 571.67 -3409.79 3457.36 0.84 6549.97 37.14 281.02 5327.54 582.75 -3466.09 3514.72 0.36 6644.93 37.34 280.17 5403.14 593.32 -3522.57 3572.18 0.58 6740.3 37.00 278.33 5479.14 602.58 -3579.43 3629.79 1.22 6833.96 37.27 278.73 5553.81 610.97 -3635.34 3686.31 0.38 6927.89 37.47 278.28 5628.46 619.4 -3691.73 3743.31 0.37 7024.06 37.65 278.03 5704.69 627.72 -3749.76 3801.92 0.25 7117.56 37.78 278.18 5778.65 635.78 -3806.39 3859.10 0.17 7213.22 38.07 278.03 5854.11 644.07 -3864.6 3917.87 0.31 7311.02 37.71 278.48 5931.29 652.69 -3924.05 3977.92 0.46 7404.85 37.50 279.07 6005.62 661.43 -3980.63 4035.17 0.45 7496.38 36.45 279.24 6078.75 670.19 -4034.98 4090.22 1.16 7594.55 34.45 278.8 6158.72 679.12 -4091.21 4147.15 2.05 7690.35 32.94 280.11 6238.43 687.84 -4143.63 4200.28 1.75 Olson Creek #2 43 Measured Depth (ft) Inclination ( deg) Azimuth ( deg ) TVD ( ft ) +NS- ( ft ) +EW- ( ft ) Vertical Section ( ft ) DLS (deg/100 ft ) 7783.94 30.62 280.25 6317.98 696.54 -4192.14 4249.57 2.47 7879.51 29.19 280.89 6400.82 705.28 -4238.98 4297.21 1.54 7975.42 27.87 281.26 6485.08 714.07 -4283.93 4343.00 1.39 8071.4 28.44 280.14 6569.71 722.48 -4328.43 4388.28 0.81 8167.73 28.53 280.44 6654.38 730.68 -4373.63 4434.22 0.17 8256.91 28.78 280.95 6732.63 738.62 -4415.66 4476.98 0.39 8356.31 29.79 282.44 6819.33 748.49 -4463.27 4525.57 1.25 8356.31 29.79 282.44 6819.33 748.49 -4463.27 4525.57 1.25 8436.94 30.13 282.86 6889.19 757.30 -4502.55 4565.78 0.49 8498.47 30.63 284.21 6942.27 764.59 -4532.80 4596.83 1.38 8561.31 31.12 286.43 6996.20 773.11 -4563.90 4628.91 1.97 8657.02 30.15 285.14 7078.56 786.38 -4610.83 4677.40 1.23 8753.50 30.97 297.54 7161.63 800.19 -4657.88 4726.11 1.53 8846.49 29.32 285.90 7242.05 813.64 -4702.61 4772.46 1.98 8878.14 28.89 284.88 7269.70 817.73 -4717.45 4787.78 2.08 8972.91 28.60 282.06 7352.80 828.35 -4761.76 4833.25 1.47 9068.48 28.11 281.52 7436.90 837.62 -4806.19 4878.61 0.57 9159.62 27.90 281.18 7517.37 846.04 -4848.14 4921.38 0.30 9252.30 26.56 279.49 7599.78 853.66 -4889.85 4963.78 1.66 9347.42 26.92 279.72 7684.73 860.81 -4932.05 5006.58 0.39 9442.45 26.18 277.71 7769.73 867.25 -4974.03 5049.04 1.22 9533.98 26.55 277.68 7851.74 872.70 -5014.32 5089.67 0.40 9629.74 27.31 281.43 7937.12 879.91 -5057.06 5133.01 1.94 9721.38 26.97 280.76 8018.67 887.96 -5098.07 5174.80 0.50 9819.64 26.69 279.52 8106.36 895.77 -5141.73 5219.14 0.64 9909.38 27.09 278.44 8186.40 902.10 -5181.81 5259.72 0.70 10006.33 27.08 280.14 8272.72 909.23 -5225.37 5303.86 0.80 10100.00 26.95 281.05 8357.06 917.13 -5267.64 5346.86 0.46 10193.08 27.21 278.16 8439.05 924.12 -5308.96 5388.76 1.45 10290.20 26.69 279.44 8525.62 930.85 -5352.46 5432.77 0.80 10383.06 27.44 281.08 8608.31 938.38 -5394.02 5475.01 1.14 10474.17 27.25 280.20 8689.25 946.11 -5435.15 5516.86 0.49 10570.02 27.44 277.35 8774.39 952.83 -5478.65 5560.87 1.38 10665.06 28.11 281.16 8858.49 959.96 -5522.34 5605.13 2.00 10759.46 27.31 277.67 8942.06 967.16 -5565.61 5649.00 1.92 10850.83 28.12 280.86 9022.96 974.01 -5607.53 5691.47 1.85 10947.68 28.84 282.28 9108.09 983.28 -5652.77 5737.63 1.02 11042.04 29.81 284.86 9190.36 994.14 -5697.68 5783.73 1.69 11136.86 30.30 287.41 9272.44 1007.34 -5743.29 5830.90 1.44 11228.11 30.57 289.79 9351.12 1022.09 -5787.09 5876.56 1.35 11322.08 31.92 291.01 9431.46 1039.08 -5832.77 5924.45 1.58 11419.20 31.95 292.11 9513.88 1057.96 -5880.54 5974.72 0.60 11512.71 32.84 292.90 9592.83 1077.14 -5926.82 6023.56 1.06 Ol s o n C r e e k # 2 44 4. 3 M U D R E C O R D Co n t r a c t o r : Mi S w a c o Mu d T y p e : S p u d M u d ( 1 5 0 ’ t o 2 0 2 3 ’ ) DA T E DE P T H MW VI S PV YP GE L S FL FC SO L OI L / W A T E R SA N D pH Cl 8/ 2 8 / 1 4 4 5 3 8 . 9 7 0 2 2 2 4 9 / 1 7 / 22 1 2 2 / - 2 0 / 9 8 - 9 . 7 4 0 0 8/ 2 9 / 1 4 1 5 8 1 9 . 1 7 2 2 4 2 4 9 / 2 0 / 2 5 7 1 / - 3 0 / 9 7 0 . 2 5 9 . 4 4 0 0 8/ 3 0 / 1 4 2 0 2 3 9 . 5 + 7 0 2 6 2 5 9 / 1 7 / 22 6 1 / - 4 0 / 9 6 0 . 7 5 9 . 1 4 0 0 8/ 3 1 / 1 4 2 0 2 3 9 . 5 6 7 2 1 1 9 8 / 1 4 / 1 6 8 1 / - 5 0 / 9 5 0 . 7 5 9 . 0 4 0 0 9/ 1 / 1 4 2 0 2 3 9 . 5 6 9 2 1 2 0 9 / 1 3 / 1 6 8 1 / - 5 0 / 9 5 0 . 7 5 9 . 0 4 0 0 9/ 2 / 1 4 2 0 2 3 9 . 5 6 9 2 1 2 0 9 / 1 3 / 1 6 8 1 / - 5 0 / 9 5 0 . 7 5 9 . 0 4 0 0 9/ 3 / 1 4 2 2 1 5 9 . 0 5 2 9 1 5 6 / 8 / 1 0 5 . 8 1 / 1 4 T r / 9 6 - 1 0 . 2 3 2 0 0 0 9/ 4 / 1 4 3 6 4 1 9 . 2 + 6 0 1 1 1 7 8 / 9 / 1 1 4 1 / 1 5 T r / 9 5 0 . 2 5 1 0 . 0 4 1 0 0 0 9/ 5 / 1 4 4 8 7 9 9 . 5 6 1 1 7 2 1 8 / 1 0 / 1 2 4 . 8 1/ 1 6 . 5 1 . 5 / 9 2 T r 1 0 . 1 3 4 0 0 0 9/ 6 / 1 4 6 0 1 9 9 . 5 5 5 1 8 2 0 8 / 1 0 / 1 2 4 . 4 1/ 1 6 . 5 1 . 5 / 9 2 T r 1 0 . 0 2 8 5 0 0 9/ 7 / 1 4 6 8 3 6 9 . 5 5 8 1 9 2 0 6 / 9 / 1 1 4 . 4 1/ 1 6 . 5 1 / 9 2 . 5 T r 1 0 . 0 2 7 0 0 0 9/ 8 / 1 4 7 5 4 3 9 . 4 + 5 4 1 9 1 9 5 / 7 / 1 0 4 . 2 1 / 1 6 . 5 1 / 9 2 . 5 T r 1 0 . 0 2 6 0 0 0 9/ 9 / 1 4 7 5 4 3 9 . 5 6 0 1 9 1 9 5 / 8 / 1 0 4 . 6 1/ 1 6 . 5 1 / 9 2 . 5 T r 1 0 . 0 2 6 0 0 0 9/ 1 0 / 1 4 7 7 3 3 9 . 5 5 8 1 9 2 0 6 / 9 / 1 2 5 . 4 1 / 1 7 1 / 9 2 T r 1 0 . 0 2 6 0 0 0 9/ 1 1 / 1 4 8 4 8 0 9 . 6 + 5 9 2 2 2 5 1 0 / 2 2 / 3 0 4. 4 1 / 1 9 1 / 9 0 T r 9 . 9 3 8 5 0 0 9/ 1 2 / 1 4 8 4 8 0 9 . 8 6 0 1 8 1 9 6 / 9 / 1 1 4 . 2 1/ 1 9 . 5 1 / 8 9 . 5 T r 9 . 8 3 8 0 0 0 9/ 1 3 / 1 4 8 4 8 0 9 . 8 6 0 1 8 1 9 6 / 1 0 / 1 1 4 . 2 1/ 1 9 . 0 1 / 8 9 . 5 T r 9 . 8 3 8 0 0 0 Ol s o n C r e e k # 2 45 Mu d R e c o r d ( C o n t ) : Mi S w a c o DA T E DE P T H MW VI S PV YP GE L S FL FC SO L OI L / W A T E R SA N D pH Cl 9/ 1 4 / 1 4 8 4 8 0 9 . 9 6 8 2 3 2 2 7 / 1 2 / 1 5 4 . 8 1/ 1 9 . 5 0 . 7 5 / 8 9 . 7 5 T r 9 . 7 3 4 0 0 0 9/ 1 5 / 1 4 8 4 8 0 9 . 7 6 0 2 3 2 2 7 / 1 2 / 1 5 4 . 8 1/ 1 9 . 5 0 . 7 5 / 8 9 . 7 5 T r 9 . 7 3 3 0 0 0 9/ 1 6 / 1 4 8 4 8 0 9 . 6 6 0 2 3 2 2 7 / 1 1 / 1 5 4 . 8 1/ 1 9 . 6 0 . 7 5 / 8 9 . 7 5 T r 9 . 7 3 3 0 0 0 9/ 1 7 / 1 4 8 4 8 0 9 . 3 + 6 0 1 3 1 4 5 / 6 / 8 4 . 8 1/ 1 9 . 6 0 . 5 / 9 3 . 5 T r 1 0 . 1 3 3 0 0 0 9/ 1 8 / 1 4 8 7 1 7 9 . 4 5 6 1 2 1 3 5 / 7 / 1 2 5 1 / 1 9 . 8 0 . 5 / 9 3 . 5 T r 1 0 . 3 3 3 0 0 0 9/ 1 9 / 1 4 8 9 1 1 9 . 3 + 5 4 1 2 1 6 5 / 7 / 1 2 4 . 6 1 / 1 9 . 4 2 / 9 2 T r 1 0 . 2 3 3 0 0 0 9/ 2 0 / 1 4 8 9 0 0 9 . 5 5 5 1 5 1 7 5 / 7 / 1 2 4 . 4 1 / 1 9 . 4 2 / 9 2 T r 1 0 . 2 3 2 0 0 0 9/ 2 1 / 1 4 9 8 7 8 9 . 5 + 9 2 2 0 2 1 7 / 8 / 1 3 4 . 2 1 / 1 6 2 . 5 / 9 1 . 5 T r 1 0 . 2 3 7 5 0 0 9/ 2 2 / 1 4 1 0 3 7 8 9 . 4 6 8 2 0 2 3 6 / 8 / 1 1 3 . 2 1 / 1 6 2 . 5 / 9 1 . 5 T r 9 . 9 3 1 5 0 0 9/ 2 3 / 1 4 1 0 7 9 2 9 . 4 6 6 2 2 2 4 5 / 7 / 1 0 3. 6 1 / 1 8 3 / 8 9 T r 1 0 2 9 0 0 0 9/ 2 4 / 1 4 1 1 0 2 3 9 . 3 6 1 1 9 1 8 4 / 5 / 7 4 1 / 1 8 2 / 9 0 T r 1 0 2 3 5 0 0 Ol s o n C r e e k # 2 46 4. 4 BI T R E C O R D BI T NO SI Z E MA K E TY P E S/ N JE T S (T F A ) IN OU T FE E T HO U R S AV E RO P AV E WO B CONDITION 1 1 2 . 2 5 ” H a l l i b u r t o n R o l l e r 5 2 3 1 9 7 1 3 x 2 0 1 1 7 ’ 2 0 2 3 ’ 1 9 0 6 ’ 2 8 . 5 1 2 9 1 1 3 - 3 - W T - A - E - I - N - T D 2 8 . 5 ” R e e d H y c a S K H 1 6 1 6 M E 1 9 7 9 5 5 6 X 1 3 2 0 2 3’ 7 5 4 3 ’ 5 5 2 0 ’ 8 5 1 2 9 6 1 - 1 - C T - S - X - I - N O - B H A 3 8 . 5 ” T a p p e r M i l l T S A 3 6 2 7 1 X 6 4 7 5 4 3 ’ 7 5 4 3 ’ 0 0 0 0 - RR 2 8. 5 ” R e e d H y c a S K H 1 6 1 6 M E 1 9 7 9 5 5 6 x 1 3 7 5 4 3 ’ 84 8 0 ’ 6 4 5 7 1 2 1 . 5 1 2 0 7 . 6 1 - 1 - C T - A - N / A - I - N O - T D 4 8. 5 ” R e e d H y c a S K H 1 6 1 3 M A 1 9 0 9 4 6 6 x 1 0 8 4 8 0’ 1 1 5 8 9 ’ 3 1 0 9 1 4 2 4 8 8 1 - 3 - C T - A - X - I - P N - T D Olson Creek #2 47 5 SHOW REPORTS Hydrocarbon Show Report #1 Operator: Well:API Number: Field: Date: Rig: Time: County: Depth Start End State:9626'MD 9655'MD Country:7933'TVD 7979'TVD Averages Before During After Maximum ROP (fph)69 119 124 178 WOB 8 7 11 10 RPM 80 80 83 82 Mud Weight 9.5+ 9.5+ 9.5+ 9.5+ Chloride 32,000 32,000 32,000 32,000 Total Gas 29 64 48 84 C1 (ppm)5,814 12,103 8,989 15,848 C2 (ppm)32 64 49 82 C3 (ppm)9 18 13 23 C4 (ppm) C5 (ppm) Lithology Cuttings Analysis Odor Fluorescence Cut Fluorescence Residual Cut Stain Amount Type Amount Amount Distribution Intensity Color Color Intensity Color Residual Fluorescence Cut Color Intesity Color Color Show Rating Free Oil in Mud Comments Report by: SAND/TUFFACEOUS SANDSTONE = DOMINANTLY LOOSE GRAINS, CLEAR TO WHITE TO TRANSLUCENT GRAINS, CLAST SIZE RANGES FROM UPPER FINE TO LOWER MEDIUM GRAINS, SOME LOOSE UPPER MEDIUM GRAINS, ANGULAR TO SUB ANGULAR, MODERATE TO WELL SORTED, LOW DEVELOPED SPHERICITY, SOME PRESERVED LIGHT GRAY WITH BROWNISH HUES, ASH AND SILT MATRIX SUPPORTED; TRACE MATRIX SUPPORTED SPECIMENS, TRACE LOOSE JASPER, LIGHT GREEN BROKEN GRAINS, NO SHOW OF OIL INDICATORS. KENAI BOROUGH ALASKA USA COOK INLET ENERGY 50-283-2014-00-00OLSON CREEK #2 BELUGA PATTERSON 191 September 21, 2014 10:06 AM LEES BROWNE JR. NO SHOW OF ANY OIL INDICATORS: NO ODOR, NO OIL STAIN, NO OIL CUTS. Pixler Plot 1 10 100 1000 10000 1234 pp m DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5C1/C3 Olson Creek #2 48 6 DAILY REPORTS COOK INLET ENERGY DAILY WELLSITE REPORT OLSON CREEK #2 REPORT FOR SMUSHKOV, MANIACI DATE Sep 25, 2014 DEPTH 11589.00000 PRESENT OPERATION DOWN LOADING MWD TOOL TIME 24 HOURS YESTERDAY 11504.00000 24 HOUR FOOTAGE 85' CASING INFORMATION 7" @ 8487' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11589' 9656 11512.71 32.84 292.90 9592.83 11419.20 31.95 292.11 9513.88 11322.08 31.92 291.01 9431.46 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 6.125" REED HYCA SKH1613M A190946 6X10 8480' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 38.7 @ 11548.00000 6.9 @ 11550.00000 19.9 20.27217 FT/HR SURFACE TORQUE 15 @ 11587.00000 11 @ 11524.00000 14.2 15.52000 AMPS WEIGHT ON BIT 21 @ 11525.00000 0 @ 11538.00000 11.6 4.92000 KLBS ROTARY RPM 83 @ 11505.00000 82 @ 11587.00000 84.0 82.91000 RPM PUMP PRESSURE 3998 @ 11511.00000 2843 @ 11588.00000 3480.5 2963.98999 PSI DRILLING MUD REPORT DEPTH 11589' MW 9.4+ VIS 82 PV 20 YP 21 FL 3.6 Gels 5/6/8 CL- 23000 FC 1/1 SOL 8 SD TR OIL 2/90 MBL 7.5 pH 10 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 54 @ 11578.00000 15 @ 11539.00000 27.4 TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 10473 @ 11578.00000 2556 @ 11539.00000 4913.3 CONNECTION GAS HIGH 46 ETHANE (C-2) 83 @ 11578.00000 21 @ 11539.00000 39.9 AVG 46 PROPANE (C-3) 16 @ 11550.00000 0 @ 11565.00000 5.3 CURRENT 46 BUTANE (C-4) 0 @ 11589.00000 0 @ 11589.00000 0.0 CURRENT BACKGROUND/AVG 0 PENTANE (C-5) 0 @ 11589.00000 0 @ 11589.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAND, CONGLOMERATE SAND, ASH, SILTSTONE, CARBON SHALE PRESENT LITHOLOGY 11589 = 60% SAND, 30% SILTSTONE, 10% ASH DAILY ACTIVITY SUMMARY DRILL FORMATION FROM 11504' TO 11589' (TD). CIRCULATE THE HOLE CLEAN AT 270 GPM AND 2936 PSI. TRIP OUT OF THE HOLE FROM 11589' TO 9101'. PUMP OUT FROM 9101' TO 8475'. CIRCULATE BOTTOMS UP TWICE AT THE SHOE AND FLOW CHECK THE WELL. PUMP A 20 BBL DRY JOB AND TRIP OUT OF THE HOLE ON ELEVATORS FROM 8445' TO THE BHA. LAY DOWN THE STRING AGITATOR AND WORK THE BHA OUT AND JARS PLUS 2 JOINTS OF HWDP. HOLD A PRE JOB SAFETY MEETING ON PULLING THE SOURCES. PULL THE SOURCES AND START TO DOWN LOAD THE MWD TOOL AT MIDNIGHT. CANRIG PERSONNEL ON BOARD BROWNE, BAKER + 2 SC DAILY COST $2985 REPORT BY LEES F. BROWNE JR. COOK INLET ENERGY DAILY WELLSITE REPORT OLSON CREEK #2 REPORT FOR SMUSHKOV, MANIACI DATE Sep 24, 2014 DEPTH 11504.00000 PRESENT OPERATION DRILLING TIME 24 HOURS YESTERDAY 10849.00000 24 HOUR FOOTAGE 655' CASING INFORMATION 7" @ 8487' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11419 31.95 292.11 9513 11322.08' 31.92 291.01 9431.46' 11228.11' 30.57 289.79 9351.12' 11136.86' 30.30 287.41 9272.44' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 6.125" REED HYCA SKH1613M A190946 6X10 8480' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 133.5 @ 11249.00000 1.4 @ 11430.00000 49.0 21.03477 FT/HR SURFACE TORQUE 15 @ 11403.00000 9 @ 11490.00000 13.4 12.50000 AMPS WEIGHT ON BIT 32 @ 11502.00000 0 @ 11399.00000 7.9 17.49000 KLBS ROTARY RPM 85 @ 11477.00000 46 @ 11491.00000 80.2 83.24000 RPM PUMP PRESSURE 3897 @ 11015.00000 3049 @ 11433.00000 3518.3 3870.00000 PSI DRILLING MUD REPORT DEPTH 11023' MW 9.3 VIS 61 PV 19 YP 18 FL 4 Gels 4/5/7 CL- 23500 FC 1/1 SOL 8 SD TR OIL 2/90 MBL 5.75 pH 10 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 205 (COAL) @ 11162.00000 2 @ 11059.00000 44.3 TRIP GAS - CUTTING GAS 0 @ 11504.00000 0 @ 11504.00000 0.0 WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 40463 @ 11162.00000 472 @ 11059.00000 8387.6 CONNECTION GAS HIGH 28 ETHANE (C-2) 258 @ 11162.00000 2 @ 11059.00000 60.6 AVG 20 PROPANE (C-3) 63 @ 11162.00000 0 @ 10881.00000 11.8 CURRENT 8 BUTANE (C-4) 0 @ 11504.00000 0 @ 11504.00000 0.0 CURRENT BACKGROUND/AVG 24 PENTANE (C-5) 0 @ 11504.00000 0 @ 11504.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAND, SANDSTONE, CONGLOMERATE SAND, TUFFACEOUS SILT, COAL, CARBON SHALE PRESENT LITHOLOGY 11500' = 90% SAND, 10% CONGLOMERATE SAND DAILY ACTIVITY SUMMARY DRILL FORMATION FROM 10849' TO 11504' CANRIG PERSONNEL ON BOARD BROWNE, BAKER + 2 SC DAILY COST $2985 REPORT BY LEES F. BROWNE JR. COOK INLET ENERGY DAILY WELLSITE REPORT OLSON CREEK #2 REPORT FOR GRUBB, MANIACI DATE Sep 23, 2014 DEPTH 10849.00000 PRESENT OPERATION DRILLING TIME 24 HOURS YESTERDAY 10414.00000 24 HOUR FOOTAGE 435 CASING INFORMATION 7" 8475' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10759.46' 27.31 277.67 8942.01 10665.06 28.11 281.16 8858.49 10570.02 27.44 277.35 8774.39 10474.17 27.25 280.20 8689.25 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 6.125" REED HYCA SKH1613M A190946 6X10 8480' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 117.2 @ 10562.00000 0.9 @ 10446.00000 33.3 41.49282 FT/HR SURFACE TORQUE 12 @ 10779.00000 9 @ SLIDE 9.0 11.95000 AMPS WEIGHT ON BIT 15 @ 10456.00000 0 @ SLIDE 9.9 8.06000 KLBS ROTARY RPM 85 @ 10511.00000 69 @ SLIDE 65.2 80.97000 RPM PUMP PRESSURE 3711 @ 10558.00000 3140 @ 10414.00000 3492.9 3532.10010 PSI DRILLING MUD REPORT DEPTH 10792' MW 9.4 VIS 66 PV 22 YP 24 FL 3.6 Gels 5/7/10 CL- 29000 FC 1/1 SOL 8 SD TR OIL 3/89 MBL 6.25 pH 10 Ca+ 130 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 123 (COAL) @ 10655.00000 2 @ 10597.00000 18.4 TRIP GAS - CUTTING GAS 0 @ 10849.00000 0 @ 10849.00000 0.0 WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 25102 @ 10655.00000 395 @ 10597.00000 3308.0 CONNECTION GAS HIGH 0 ETHANE (C-2) 147 @ 10655.00000 1 @ 10746.00000 26.0 AVG 0 PROPANE (C-3) 27 @ 10759.00000 0 @ 10678.00000 1.5 CURRENT 0 BUTANE (C-4) 0 @ 10849.00000 0 @ 10849.00000 0.0 CURRENT BACKGROUND/AVG 14 PENTANE (C-5) 0 @ 10849.00000 0 @ 10849.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS SILTSTONE, TUFFACEOUS SANDSTONE, ASH, SAND, COAL, CARBON CLAY PRESENT LITHOLOGY 10840' = 80% TUFFACEOUS SILTSTONE, 20% CARBON CLAY DAILY ACTIVITY SUMMARY DRILL FORMATION FROM 10414' TO 10514'. WORK ON MUD PUMPS #1 AND #2. DRILL SLIDE FROM 10514' TO 10703'. SERVICE THE RIG. DRILL FROM 10703' TO 10849' (MIDNIGHT). CANRIG PERSONNEL ON BOARD BROWNE, BAKER + 2 SC DAILY COST $2985 REPORT BY LEES F. BROWNE JR. COOK INLET ENERGY DAILY WELLSITE REPORT OLSON CREEK #2 REPORT FOR GRUBB, MANIACI DATE Sep 22, 2014 DEPTH 10414.00000 PRESENT OPERATION DRILLING TIME 24 HOURS YESTERDAY 9880.00000 24 HOUR FOOTAGE 534' CASING INFORMATION 7" @ 8475' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10290.20' 26.69 279.44 8525.57' 10193.00' 27.21 278.16 8438.00' 10101.00' 26.95 281.05 8357.00' 10006.33' 27.08 280.14 8282.68' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 6.125" REED HYCA SKH1613M A190946 6X10 8480' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 140.4 @ 9897.00000 0.5 @ 10092.00000 47.0 8.27844 FT/HR SURFACE TORQUE 16 @ 9920.00000 2 @ SLIDE 10.6 9.49000 AMPS WEIGHT ON BIT 26 @ 10265.00000 0 @ SLIDE 8.1 8.97000 KLBS ROTARY RPM 86 @ 10067.00000 0 @ SLIDE 69.7 75.75000 RPM PUMP PRESSURE 3699 @ 10104.00000 2796 @ 10272.00000 3331.4 3140.77002 PSI DRILLING MUD REPORT DEPTH 10378' MW 9.4 VIS 68 PV 20 YP 23 FL 3.2 Gels 6/8/11 CL- 31500 FC 1/1 SOL 6 SD TR OIL 2.5/91.5 MBL 7 pH 9.9 Ca+ 180 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 174 @ 9894.00000 1 @ 10302.00000 22.4 TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 29459 @ 10097.00000 232 @ 10302.00000 4126.7 CONNECTION GAS HIGH 0 ETHANE (C-2) 144 @ 10096.00000 0 @ 10298.00000 30.3 AVG 0 PROPANE (C-3) 20 @ 10197.00000 0 @ 10048.00000 1.3 CURRENT 0 BUTANE (C-4) 0 @ 10414.00000 0 @ 10414.00000 0.0 CURRENT BACKGROUND/AVG 7 PENTANE (C-5) 0 @ 10414.00000 0 @ 10414.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS SILTSTONE, TUFFACEOUS SANDSTONE, ASH, SAND, CARBON CLAY, COAL PRESENT LITHOLOGY 10410' = 70% CARBONACEOUS CLAY, 20% TUFFACEOUS SILTSTONE, 10% COAL DAILY ACTIVITY SUMMARY DRILL/SLIDE FROM 9880' TO 10414'. CANRIG PERSONNEL ON BOARD BROWNE, BAKER + 2 SC DAILY COST $2985 REPORT BY LEES F. BROWNE JR. COOK INLET ENERGY DAILY WELLSITE REPORT OLSON CREEK #2 REPORT FOR GRUBB, MANIACI DATE Sep 21, 2014 DEPTH 9880.00000 PRESENT OPERATION DRILLING TIME 24 HOURS YESTERDAY 9337.00000 24 HOUR FOOTAGE 543' CASING INFORMATION 7" @ 8475' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9819.64' 26.69 279.52 8106.29' 9721.38' 26.97 280.76 8018.67' 9629.74' 27.31 281.43 7937.12' 9533.98' 26.55 277.68 7851.74' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 6.125" REED HYCA SKH1613M A190946 6X10 8480' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 178.6 @ 9630.00000 0.6 @ 9338.00000 54.1 67.11563 FT/HR SURFACE TORQUE 14 @ 9653.00000 3 @ SLIDE 11.6 13.49000 AMPS WEIGHT ON BIT 19 @ 9837.00000 0 @ SLIDE 8.5 9.19000 KLBS ROTARY RPM 85 @ 9460.00000 70 @ SLIDE 70.3 71.03000 RPM PUMP PRESSURE 3613 @ 9774.00000 2987 @ 9668.00000 3330.1 3491.20996 PSI DRILLING MUD REPORT DEPTH 9878' MW 9.5+ VIS 92 PV 20 YP 21 FL 4.2 Gels 7/8/13 CL- 37500 FC 1/1 SOL 6 SD TR OIL 2.5/91.5 MBL 7.5 pH 10.2 Ca+ 160 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 902 (COAL) @ 9609.00000 1 @ 9715.00000 36.4 TRIP GAS - CUTTING GAS @ @ WIPER GAS 331 @ 9814' CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 177099 @ 9609.00000 194 @ 9715.00000 6897.4 CONNECTION GAS HIGH 0 ETHANE (C-2) 791 @ 9609.00000 1 @ 9715.00000 38.9 AVG 0 PROPANE (C-3) 188 @ 9610.00000 0 @ 9587.00000 4.1 CURRENT 0 BUTANE (C-4) 0 @ 9880.00000 0 @ 9880.00000 0.0 CURRENT BACKGROUND/AVG 10 PENTANE (C-5) 0 @ 9880.00000 0 @ 9880.00000 0.0 HYDROCARBON SHOWS GAS SHOW #1 INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 9626' TO 9655' 60% SAND, 40% TUFFACEOUS SAND BEFORE 29 DURING 64 AFTER 48 DOM LOOSE GRAINS CLEAR-WHITE-TRANSL, FINE UPPER TO MEDIUM LOWER; ANG-SBANG, MOD TO WELL SORT, ASH/SILT MATRIX SUPPORTED SEE SHOW REPORT #1 LITHOLOGY TUFFACEOUS SILTSTONE, TUFFACEOUS SANDSTONE, SAND, COAL, CARBON CLAY, ASH PRESENT LITHOLOGY 9880' = 100% TUFFACEOUS SILTSTONE DAILY ACTIVITY SUMMARY DRILL/SLIDE FORMATION FROM 9337' TO 9814'. CIRCULATE BOTTOMS UP FOR WIPER TRIP. PULL OUT OF THE HOLE FROM 9814' TO 8475'. SERVIVE THE RIG AND TRIP IN THE HOLE TO 9814'. WIPER GAS WAS 331 UNITS. DRILL/SLIDE FROM 9814' TO 9880' (MIDNIGHT). CANRIG PERSONNEL ON BOARD BROWNE, BAKER + 2 SC DAILY COST $2985 REPORT BY LEES F. BROWNE JR. COOK INLET ENERGY DAILY WELLSITE REPORT OLSON CREEK #2 REPORT FOR GRUBB, MANIACI DATE Sep 20, 2014 DEPTH 9337.00000 PRESENT OPERATION DRILLING TIME 24 HOURS YESTERDAY 8911.00000 24 HOUR FOOTAGE 426' CASING INFORMATION 7" @ 8475' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9159 27.90 281.18 7517 9068.48 28.11 281.52 7436.90 8972.91 28.60 282.06 7352.80 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 6.125" REED HYCA SKH1613M A190946 6X10 8480' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 409.0 @ 9069.00000 0.7 @ 9239.00000 58.9 7.37533 FT/HR SURFACE TORQUE 13 @ 9261.00000 10 @ SLIDE 10.4 0.00000 AMPS WEIGHT ON BIT 16 @ 9180.00000 0 @ SLIDE 6.8 12.39000 KLBS ROTARY RPM 82 @ 9014.00000 39 @ SLIDE 64.5 0.00000 RPM PUMP PRESSURE 3289 @ 9109.00000 2379 @ 8911.00000 2970.8 3040.40991 PSI DRILLING MUD REPORT DEPTH 8900' MW 9.5 VIS 55 PV 15 YP 17 FL 4.4 Gels 5/7/12 CL- 32000 FC 1/1 SOL 6 SD TR OIL 2/92 MBL 7.5 pH 10.2 Ca+ 70 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 293 @ 9197.00000 1 @ 9086.00000 23.8 TRIP GAS - CUTTING GAS @ @ WIPER GAS 51 @ 8911' CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 55749 @ 9197.00000 110 @ 9086.00000 3881.4 CONNECTION GAS HIGH 6 ETHANE (C-2) 260 @ 9197.00000 0 @ 9276.00000 26.6 AVG 3 PROPANE (C-3) 87 @ 9197.00000 0 @ 9314.00000 2.3 CURRENT 0 BUTANE (C-4) 0 @ 9337.00000 0 @ 9337.00000 0.0 CURRENT BACKGROUND/AVG 18 PENTANE (C-5) 0 @ 9337.00000 0 @ 9337.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS SILTSTONE, SAND, TUFFACEOUS SAND STONE, ASH, COAL, CARBON CLAY + SHALE PRESENT LITHOLOGY 9330' = 40% TUFFACEOUS SILT, 40% CARBONACEOUS SHALE/CLAY, 10% ASH, 10% COAL DAILY ACTIVITY SUMMARY TRIP IN THE HOLE FROM 5320' TO 8911' TD (WASH DOWN THE LAST TWO STANDS. WIPER GAS WAS 51 UNITS. DRILL/SLIDE FROM 8911' TO 9337' (MIDNIGHT). CANRIG PERSONNEL ON BOARD BROWNE, BAKER + 2 SC DAILY COST $2985 REPORT BY LEES F. BROWNE JR. COOK INLET ENERGY DAILY WELLSITE REPORT OLSON CREEK #2 REPORT FOR GRUBB, MANIACI DATE Sep 19, 2014 DEPTH 8911.00000 PRESENT OPERATION TRIP IN HOLE TO DRILL TIME 24 HOURS YESTERDAY 8763.00000 24 HOUR FOOTAGE 148' CASING INFORMATION 7" @ 8475' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8753.50' 30.97 287.54 7161.63' 8657.02 30.15 285.14 7078.56' 8561.31 31.12 286.43 6996.20' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 6.125" REED HYCA SKH1613M A190946 6X10 8480' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 277.0 @ 8886.00000 1.1 @ 8824.00000 37.8 34.49818 FT/HR SURFACE TORQUE 12 @ 8886.00000 11 @ SLIDE 9.1 12.52000 AMPS WEIGHT ON BIT 14 @ 8885.00000 0 @ SLIDE 3.6 3.66000 KLBS ROTARY RPM 83 @ 8813.00000 76 @ SLIDE 60.7 79.69000 RPM PUMP PRESSURE 2450 @ 8909.00000 1179 @ 8850.00000 2213.5 2379.08008 PSI DRILLING MUD REPORT DEPTH 8911' MW 9.3+ VIS 54 PV 12 YP 16 FL 4.6 Gels 5/7/12 CL- 3300 FC 1/1 SOL 6 SD tr OIL 2/92 MBL 5 pH 10.2 Ca+ 70 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 57 (COAL) @ 8892.00000 1 @ 8876.00000 14.7 TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 11560 @ 8892.00000 394 @ 8876.00000 2533.2 CONNECTION GAS HIGH 9 ETHANE (C-2) 185 @ 8873.00000 1 @ 8906.00000 24.3 AVG 9 PROPANE (C-3) 25 @ 8812.00000 1 @ 8796.00000 1.9 CURRENT 9 BUTANE (C-4) 0 @ 8911.00000 0 @ 8911.00000 0.0 CURRENT BACKGROUND/AVG 0 TIH PENTANE (C-5) 0 @ 8911.00000 0 @ 8911.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS SILTSTONE, COAL, CARBON SHALE, TUFFACEOUS SANDSTONE, ASH PRESENT LITHOLOGY 8910' = 60% TUFFACEOUS SILTSTONE, 20% ASH, 20% TUFFACEOUS SANDSTONE DAILY ACTIVITY SUMMARY DRILL/SLIDE TO 8911'. CIRCULATE BOTTOMS UP AND PULL OUT OF THE HOLE FROM 8911' TO 4300'. SECURE THE WELL AND TROUBLE SHOOT INERTIA BRAKE. COOL OFF INERTIA BRAKE AND SHUT OFF THE AIR SUPPLY TO DAMAGED INERTIA BRAKE. PULL OUT OF THE HOLE FROM 4300' TO 1634' AND SERVICE THE RIG AND WAIT ON PEAK TO DELIVER AGITATOR. PICK UP AGITATOR AND CROSS OVER'S AND TEST THE AGITATOR. THE AGITATOR IS WEAK. LAY DOWN AND PICK UP NEW STRING AGITATOR AND RETEST AT 240 GPM. TRIP IN THE HOLE FROM 1634' TO 5320' AT MIDNIGHT. CANRIG PERSONNEL ON BOARD BROWNE, BAKER + 2 SC DAILY COST $2985 REPORT BY LEES F. BROWNE JR. COOK INLET ENERGY DAILY WELLSITE REPORT OLSON CREEK #2 REPORT FOR GRUBB, MANIACI DATE Sep 18, 2014 DEPTH 8763.00000 PRESENT OPERATION DRILLING TIME 24 HOURS YESTERDAY 8480.00000 24 HOUR FOOTAGE 283' CASING INFORMATION 7" @ 8475' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8561.34' 31.12 286.43 6996.00' 8498.47' 30.63 284.21 6942.00' 8436.94' 30.13 282.86 6889.19' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 6.125" REED HYCA SKH1613M A190946 6X10 8480' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 125.7 @ 8531.00000 0.9 @ 8742.00000 59.1 39.95023 FT/HR SURFACE TORQUE 21 @ 8480.00000 9 @ SLIDE 10.9 11.66000 AMPS WEIGHT ON BIT 12 @ 8640.00000 0 @ SLIDE 4.1 3.62000 KLBS ROTARY RPM 80 @ 8746.00000 29 @ SLIDE 38.5 80.93000 RPM PUMP PRESSURE 2760 @ 8480.00000 1045 @ 8481.00000 2375.0 2268.64990 PSI DRILLING MUD REPORT DEPTH 8717' MW 9.4 VIS 56 PV 12 YP 13 FL 5 Gels 5/7/12 CL- 33000 FC 1/1 SOL 6 SD tr OIL 0.5/93.5 MBL 5 pH 10.3 Ca+ 68 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 147 @ 8524.00000 0 @ 8481.00000 18.6 TRIP GAS 4 @ 8480' CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 30106 @ 8524.00000 22 @ 8481.00000 3487.0 CONNECTION GAS HIGH 23 AFTER COAL ETHANE (C-2) 69 @ 8527.00000 0 @ 8510.00000 14.5 AVG 7 PROPANE (C-3) 21 @ 8527.00000 0 @ 8510.00000 1.5 CURRENT 0 BUTANE (C-4) 0 @ 8763.00000 0 @ 8763.00000 0.0 CURRENT BACKGROUND/AVG 15 PENTANE (C-5) 0 @ 8763.00000 0 @ 8763.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS SILTSTONE, TUFFACEOUS SANDSTONE, ASH, SAND, CONGLOMERATE, CONGLOMERATE SAND, COAL, CARBON SHALE & CLAY PRESENT LITHOLOGY 8760' = 100% TUFFACEOUS SILTSTONE DAILY ACTIVITY SUMMARY PICK UP 4" DRILL PIPE FROM 5489' to 8391'. SERVICE THE RIG AND WASH DOWN FROM 8286' AND TAG CEMENT AT 8392'. PUMP A FULL CIRCULATION WITH 9.4 PPG MUD AT 200 GPM AND 10 RPM. HOLD A PRE JOB SAFETY MEETING ON THE CASING TEST AND TEST THE CASING TO 5000 PSI = GOOD TEST. DRILL OUT PLUGS, FLOAT COLLAR AND SHOE TRACK FROM 8392' TO 8476'. TAG THE SHOE AT 8476'. DRILL 20' OF NEW HOLE FROM 8460' TO 8500'. TRIP GAS WAS 4 UNITS. CIRCULATE BOTTOMS UP TO CLEAN THE HOLE FOR THE F.I.T. PERFORM THE F.I.T. TO 3000 17.1 EMW = GOOD TEST. DRILL AND SLIDE FROM 8500' TO 8763' AT MIDNIGHT. CANRIG PERSONNEL ON BOARD BROWNE, BAKER + 2 SC DAILY COST $2985 REPORT BY LEES F. BROWNE JR. COOK INLET ENERGY DAILY WELLSITE REPORT OLSON CREEK #2 REPORT FOR MANIACI DATE Sep 17, 2014 DEPTH 8480.00000 PRESENT OPERATION PICKING UP 4" DRILL PIPE TIME 24 HOURS YESTERDAY 8480.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 7" @ 8475' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8436.94' 30.13 282.86 6889.19' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 6.125" REED HYCA SKH1613M A190946 6X10 8480' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 8480' (Pit #6) MW 9.3+ VIS 60 PV 13 YP 14 FL 4.8 Gels 5/6/8 CL- 3300 FC 1/1 SOL 6 SD tr OIL 0.5/93.5 MBL 6.25 pH 10.1 Ca+ 90 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) @ @ CONNECTION GAS HIGH - ETHANE (C-2) @ @ AVG - PROPANE (C-3) @ @ CURRENT - BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG - PENTANE (C-5) @ @ HYDROCARBON SHOWS NO MUD CIRCULATED THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 100% CEMENT DAILY ACTIVITY SUMMARY PICK UP AND STRAP 4" DRILL PIPE TO 4141' AND RUN IN THE HOLE. INSTALL STRIPPING RUBBERS, CLEAN THE RIG FLOOR AND RACK BACK 44 STANDS OF DRILL PIPE. SERVICE THE RIG AND BRING TOOLS TO THE RIG FLOOR. CHANGE OUT THE ELEVATORS AND HOLD A PRE JOB SAFETY MEETING ON MAKING UP THE BHA. MAKE UP THE BHA AND DOWN LOAD THE HALLIBURTON TOOLS. HOLD A PRE JOB SAFETY MEETING WITH HALLIBURTON ON LOADING THE SOURCES AND LOAD THE SAME. PICK UP THE BHA AND FLEX COLLARS. CHANGE OUT THE ELEVATORS AND PICK UP THE HWDP, JARS AND CROSS OVERS. PICK UP 4000' OF DRILL PIPE. CANRIG PERSONNEL ON BOARD BROWNE, BAKER + 2 SC DAILY COST $2985 REPORT BY LEES F. BROWNE JR. COOK INLET ENERGY DAILY WELLSITE REPORT OLSON CREEK #2 REPORT FOR LUNDA, GRUBB DATE Sep 16, 2014 DEPTH 8480.00000 PRESENT OPERATION FINISHING TEST BOPE TIME 24 HOURS YESTERDAY 8480.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 7" @ 8480' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8436.94' 30.13 282.86 6889.19' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 8480 MW 9.7 VIS 62 PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 0 @ 0 0 @ 0 0 TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) @ @ CONNECTION GAS HIGH - ETHANE (C-2) @ @ AVG - PROPANE (C-3) @ @ CURRENT - BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG - PENTANE (C-5) @ @ HYDROCARBON SHOWS NO MUD CIRCULATED THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 100% CEMENT DAILY ACTIVITY SUMMARY LAY DOWN 5" TOOLS AND PICK UP 4" TOOLS. TEST SUBS AND SAER SUBS. START CLEANING OUT THE MUD TANKS. CHANGE OUT 5" SAVER SUB, GRABBER BOX AND STABILIZER GUIDE. BUILD TEST ASSEMBLY AND R/I HOLE. CHANGE OUT 7" CASING RAMS TO 2 7/8 X 5" PIPE RAMS. PULL AND REINSTALL MOUSE HOLE AND SERVICE CHOKE VALVE. FLUSH THE STACK, TOP DRIVE AND CHOKE LINES FOR BOP TESTING. PRESSURE UP ON NEW TEST PUMP TO ENSURE NO LEAKS. TEST THE BOP EQUIPMENT. CHANGE OUT SAVER SUB, DIE BLOCKS AND STABBING GUIDE. RIG UP FOR TESTING IBOP'S AND TEST THE SAME. RIG DOWN THE TEST EQUIPMENT AND PREP TO PICK UP 4000' OF DRILL PIPE AND RACK BACK IN THE DERRICK. CANRIG PERSONNEL ON BOARD BROWNE, BAKER + 2 SC DAILY COST $2985 REPORT BY LEES F. BROWNE JR. COOK INLET ENERGY DAILY WELLSITE REPORT OLSON CREEK #2 REPORT FOR DATE Sep 15, 2014 DEPTH 8480.00000 PRESENT OPERATION PREP TO TEST BOPE TIME 21:37:42 YESTERDAY 8480.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 7" @ 8480' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8436.94' 30.13 282.86 6889.19' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 8480' MW 9.7 VIS 60 PV 23 YP 22 FL 4.8 Gels 7/12/15 CL- 33000 FC 1/1 SOL 9.5 SD tr OIL 0.75/89.75 MBL 9 pH 9.7 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 48 @ CIRC O @ 8480 15 CIRC TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) @ @ CONNECTION GAS HIGH - ETHANE (C-2) @ @ AVG - PROPANE (C-3) @ @ CURRENT - BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 100% CEMENT DAILY ACTIVITY SUMMARY CIRCULATE AT 5 BPM TO CLEAN UP THE HOLE AT 8480' WHILE RIGGING UP FOR CEMENT JOB. CEMENT HOLE AS PER PROGRAM AND LAY DOWN THE LANDING JOINT. WASH DOWN STACK AND DRAIN. EMPTY THE CELLER AND VERIFY THE TOP OF THE HANGER IS CLEAR. LAND PACK OFF ON TOP OF THE HANGER. TEST VOID TO 5000 PSI FOR TEN MINUTES. LAY DOWN THE CASING CRT, SERVICE LOOP, TONGS. PREP FLOOR AND PICK UP THREAD PROTECTORS FOR LAYING DOWN THE DRILL PIPE. LAY DOWN 5" DRILL PIPE AND LAY DOWN HWDP (7 STANDS). SERVICE THE RIG AND PREP FLOOR FOR CHANGING 7" RAMS AND TESTING BOPE. CANRIG PERSONNEL ON BOARD BROWNE, BAKER + 2 SC DAILY COST $2985 REPORT BY LEES F. BROWNE JR. COOK INLET ENERGY DAILY WELLSITE REPORT OLSON CREEK #2 REPORT FOR GRUBB/LUNDA DATE Sep 14, 2014 DEPTH 8480.00000 PRESENT OPERATION CIRCULATION WITH CASING ON BOTTOM TIME 24 HOURS YESTERDAY 8480.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9.625" @ 2023' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8436.94' 30.13 282.86 6889.19' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 8480' MW 9.9 VIS 68 PV 23 YP 22 FL 4.8 Gels 7/12/15 CL- 34000 FC 1/1 SOL 9.5 SD tr OIL 0.75/89.75 MBL 9 pH 9.7 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 128 @ TG 0 @ TIH 15 (TIH) TRIP GAS 128 @ 8450' CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) @ @ CONNECTION GAS HIGH - ETHANE (C-2) @ @ AVG - PROPANE (C-3) @ @ CURRENT - BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 8480' = 100% TUFFACEOUS SILTSTONE DAILY ACTIVITY SUMMARY RUN 7" CASING AT 25 FPM TO 300'. CHANGE OUT POWER TONGS DUE TO NOT READING TORQUE. RUN CASING FROM 300' TO 2010' FILLING EVERY JOINT ON THE RUN. CIRCULATE BOTTOMS UP AT 2012' @ 2.5 B/M. MAXIMUM GAS WAS 10 UNITS. RUN 7" CASING FROM 2012' TO 8450' FILLING PIPE ON THE RUN. CIRCULATE CASING AT 8450' AT 188 GPM. MAXIMUM TRIP GAS WAS 128 UNITS. BUILDING SPACER FOR CEMENT JOB. TAG BOTTOM AND CIRCULATE. LAY DOWN A PUP AND SINGLE AND PICK UP LANDING JOINT. CANRIG PERSONNEL ON BOARD BROWNE, BAKER + 2 SC DAILY COST $2985 REPORT BY LEES F. BROWNE JR. COOK INLET ENERGY DAILY WELLSITE REPORT OLSON CREEK #2 REPORT FOR GRUBB, LUNDA DATE Sep 13, 2014 DEPTH 8480.00000 PRESENT OPERATION RIG UP TO RUN CASING TIME 24 HOURS YESTERDAY 8480.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9.625" @ 2023' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8436.94' 30.13 282.86 6889.19' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 RR#2 8.5" REED HYCA SKH1616H E197955 6X13 2023 8480 6457 121.5 1-1-CT-A-N/A-I-NO TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 8480' MW 9.8 VIS 60 PV 18 YP 19 FL 4.2 Gels 6/9/11 CL- 38000 FC 1/1 SOL 9.5 SD tr OIL 1/89.5 MBL 9 pH 9.8 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 24 @ 2023' 0 @ TOOH 8 CIRC TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) @ @ CONNECTION GAS HIGH - ETHANE (C-2) @ @ AVG - PROPANE (C-3) @ @ CURRENT - BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 8480' = 100% TUFFACEOUS SILTSTONE DAILY ACTIVITY SUMMARY CIRCULATE HOLE AT 8480' (TD) AND FLOW CHECK THE WELL. PULL OUT OF THE HOLE FROM 8480' TO 7830'. PUMP A 15 BBL DRY JOB AND TRIP OUT OF THE HOLE TO 2100'. CIRCULATE BOTTOMS UP FOUR TIMES AT 550 GPM AND PUMP A 15 BBL DRY JOB. MAXIMUM GAS WAS 24 UNITS. TRIP OUT OF THE HOLE FROM 2100' TO 440'. LAY DOWN THE JARS AND STAND BACK THE HWDP. LAY DOWN THE COLLARS AND HOLD A PRE JOB SAFETY MEETING ON NUKE SOURCES. REMOVE THE NUKE SOURCES AND DOWN LOAD THE MWD TOOLS. LAY DOWN THE MWD, MOTOR AND BHA. PICK UP THE 7" TEST JOINT AND 8' PUP JOINT. PULL THE WEAR BUSHING AND SET THE TEST PLUG. PULL THE WEAR RING AND SET THE TEST PLUG. CHANGE OUT THE UPPER RAMS TO 7". FILL THE STACK AND TEST THE UPPER RAMS AND HYDRIL TO 250 LOW AND 3000 HIGH. RIG DOWN THE TEST JOINT AND TEST PUMP. SERVICE THE RIG AND REMOVE ELEVATORS AND BAILS FROM THE TOP DRIVE FOR THE CRT. RIG UP THE CASING EQUIPMENT AND PICK UP THE CRT WITH THE BLOCKS. RIG UP THE CRT TO THE TOP DRIVE. PICK UP THE POWER TONGS AND HOLD A PRE JOB SAFETY MEETING ON RUNNING THE CASING. MAKE UP THE SHOE AND FLOATS AND RUN IN THE HOLE TO 128' TO CHECK THE FLOATS. PREP TO RUN CASING. CANRIG PERSONNEL ON BOARD BROWNE, BAKER + 2 SC DAILY COST $2985 REPORT BY LEES F. BROWNE JR. COOK INLET ENERGY DAILY WELLSITE REPORT OLSON CREEK #2 REPORT FOR GRUBB, LUNDA DATE Sep 12, 2014 DEPTH 8480.00000 PRESENT OPERATION CIRCULATE ON BOTTOM TIME 24 HOURS YESTERDAY 8480.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9.625" @ 2023' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8436.94' 30.13 282.86 6889.19' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 RR#2 8.5" REED HYCA SKH1616H E197955 6X13 2023 8480 6457 121.5 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 8480' MW 9.8 VIS 67 PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 483 @ WG 0 @ POOH 15 CIRC TRIP GAS - CUTTING GAS @ @ WIPER GAS 483 CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) @ @ CONNECTION GAS HIGH - ETHANE (C-2) @ @ AVG - PROPANE (C-3) @ @ CURRENT - BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 15 PENTANE (C-5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 100% TUFFACEOUS SILTSTONE DAILY ACTIVITY SUMMARY CIRCULATE BOTTOMS UP AT 8480'. PULL OUT OF THE HOLE TO 2080'. CIRCULATE BOTTOMS UP THREE TIMES AT 550 GPM. MAXIMUM GAS WAS 165 UNITS. CONDUCT A TRIP DRILL AND HOLD A PRE JOB SAFETY MEETING ON THE SAME. CUT AND SLIP 60' OF DRILL LINE AND SERVICE THE RIG. RESPOOL DRILL LINE, FIX WRAPS AND CALIBRATE THE SAME. TRIP IN THE HOLE ON ELEVATORS FROM 2023' TO 8480'. WASHING AS NEEDED. WIPER GAS WAS 483 UNITS SHOWING SOME GAS MIGRATION. 8' OF FILL NOTED ON BOTTOM. PUMP A HIGH VISCOSITY SWEEP AND CIRCULATE BOTTOMS UP THREE TIMES AT 500 GPM TO CLEAN THE HOLE. CANRIG PERSONNEL ON BOARD BROWNE, BAKER + 2 SC DAILY COST $2985 REPORT BY LEES F. BROWNE JR. COOK INLET ENERGY DAILY WELLSITE REPORT OLSON CREEK #2 REPORT FOR GRUBB, LUNDA DATE Sep 11, 2014 DEPTH 8480.00000 PRESENT OPERATION CIRCULATE AT CASING DEPTH TIME 24 HOURS YESTERDAY 7733.00000 24 HOUR FOOTAGE 747' CASING INFORMATION 9.625" @ 2023' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8436.94' 30.13 282.86 6889.19' 8356.31' 29.79 282.44 6819.33' 8256.91' 28.78 280.95 6732.63' 8167.73' 28.53 280.44 6654.38' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 4 RR#2 8.5" REED HYCA SKH1616H E197955 6X13 2023 8480 6457 121.5 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 160.6 @ 7925.00000 1.0 @ 7981.00000 69.4 94.96175 FT/HR SURFACE TORQUE 21 @ 8384.00000 0 @ 8067.00000 16.3 21.43000 AMPS WEIGHT ON BIT 61 @ 7976.00000 4 @ 8082.00000 16.7 9.51000 KLBS ROTARY RPM 95 @ 8284.00000 0 @ 8063.00000 62.9 68.88000 RPM PUMP PRESSURE 2888 @ 8230.00000 2276 @ 7754.00000 2683.3 2760.76001 PSI DRILLING MUD REPORT DEPTH 8480' MW 9.6+ VIS 59 PV 22 YP 25 FL 4.4 Gels 10/22/30 CL- 38500 FC 1/1 SOL 9 SD tr OIL 1/90 MBL 8.75 pH 9.9 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 429 (COAL) @ 8024.00000 14 @ 7850.00000 48.7 TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 70910 @ 8024.00000 2546 @ 8102.00000 8416.3 CONNECTION GAS HIGH 24 ETHANE (C-2) 325 @ 8024.00000 0 @ 7850.00000 36.9 AVG 13 PROPANE (C-3) 15 @ 7866.00000 0 @ 7876.00000 0.6 CURRENT 2 BUTANE (C-4) 0 @ 8480.00000 0 @ 8480.00000 0.0 CURRENT BACKGROUND/AVG 0 (TOOH) PENTANE (C-5) 0 @ 8480.00000 0 @ 8480.00000 0.0 HYDROCARBON SHOWS NO GAS KICKS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS SILTSTONE, SAND, TUFFACEOUS SAND, CARBON CLAY, COAL PRESENT LITHOLOGY 8480 = 100% TUFFACEOUS SILTSTONE DAILY ACTIVITY SUMMARY DRILL/SLIDE FROM 7733' TO 8305'. SERVICE THE RIG, GREASE TOP DRIVE, BLOCKS AND DRAW WORKS. DRILL/SLIDE FROM 8305' TO 8480'. CIRCULATE BOTTOMS UP TO CIRCULATE OUT SAMPLES. SAMPLES INDICATE 100% TUFFACEOUS SILTSTONE. PUMP A HIGH VISCOSITY SWEEP AROUND AND PREP TO WIPER TRIP TO THE SHOE. CANRIG PERSONNEL ON BOARD BROWNE, BAKER + 2 SC DAILY COST $2985 REPORT BY LEES F. BROWNE JR. COOK INLET ENERGY DAILY WELLSITE REPORT OLSON CREEK #2 REPORT FOR SMUSHKOV, LUNDA DATE Sep 10, 2014 DEPTH 7733.00000 PRESENT OPERATION DRILLING TIME 24 HOURS YESTERDAY 7543.00000 24 HOUR FOOTAGE 190' CASING INFORMATION 9.625" @ 2023' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 7690.35' 32.92 280.11 6238.40' 7594.55' 34.37 278.80 6158.76' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 3 8.5" TAPPER MILL TSA3627 1X64 7543 7543 0 0 BHA 4 RR #2 8.5" REED HYCA SKH1616H E197955 6X13 7543 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 120.4 @ 7646.00000 3.5 @ 7548.00000 64.6 90.63900 FT/HR SURFACE TORQUE 19 @ 7637.00000 0 @ 7690.00000 11.3 19.26000 AMPS WEIGHT ON BIT 20 @ 7664.00000 2 @ 7593.00000 9.0 7.75000 KLBS ROTARY RPM 86 @ 7712.00000 1 @ 7665.00000 50.0 86.46000 RPM PUMP PRESSURE 2996 @ 7543.00000 1979 @ 7613.00000 2509.5 2452.71997 PSI DRILLING MUD REPORT DEPTH 7733' MW 9.5 VIS 58 PV 19 YP 20 FL 5.4 Gels 6/9/12 CL- 26000 FC 1/1 SOL 7 SD tr OIL 1/92 MBL 10 pH 10 Ca+ 72 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 341 (COAL) @ 7602.00000 11 @ 7678.00000 82.2 TRIP GAS 1170 @ 7543' CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 51969 @ 7602.00000 777 @ 7583.00000 13031.4 CONNECTION GAS HIGH 43 ETHANE (C-2) 328 @ 7691.00000 1 @ 7720.00000 54.7 AVG 27 PROPANE (C-3) 21 @ 7600.00000 0 @ 7584.00000 4.2 CURRENT 10 BUTANE (C-4) 0 @ 7733.00000 0 @ 7733.00000 0.0 CURRENT BACKGROUND/AVG 31 PENTANE (C-5) 0 @ 7733.00000 0 @ 7733.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS SILTSTONE, SAND, TUFFACEOUS SANDSTONE, COAL, CARBONACEOUS SHALE PRESENT LITHOLOGY 7730' = 100% TUFFACEOUS SILTSTONE DAILY ACTIVITY SUMMARY VERY LITTLE METAL IN SAMPLES DURING MILLING RUN. TRIP OUT OF THE HOLE FROM 2693' TO BHA (888'). LAY DOWN THE BHA AND CLEAN THE RIG FLOOR. LINE OUT NEW BHA (RR BIT #2). HOLD A PRE JOB SAFETY MEETING WITH DD AND MWD SUPPORTING ROLES TO HANDLE THE BHA. UPLOAD THE MWD TOOLS AND HOLD A PRE JOB SAFETY MEETING ON LOADING SOURCES AND LOAD SOURCES. TRIP IN THE HOLE FROM BHA TO 2000'. CIRCULATE BOTTOMS UP TWICE AT THE SHOE. TRIP IN THE HOLE FROM 2000' TO 4175'. TIGHT AREA INCREASE OF PSI ON THE DRILL PIPE. FLOW CHECK: SHUT IN THE WELL AND CIRCULATE ON THE CHOKE AT SLOW PUMP RATE FOR BOTTOMS UPOPEN CHOKE AND ANNULAR WITH NO FLOW (STATIC). RUN IN HOLE ON ELEVATORS TO TIGHT ZONES OF 5921' AND 6871'. REAM TO BOTTOM FROM 6900' TO 7543'. TRIP GAS WAS 1170 UNITS (FROM MIGRATING UP HOLE COAL GAS FROM 7310'). DRILL/SLIDE FROM 7543' TO 7733' (MIDNIGHT). CANRIG PERSONNEL ON BOARD BROWNE, BAKER + 2 SC DAILY COST $2985 REPORT BY LEES F. BROWNE JR. COOK INLET ENERGY DAILY WELLSITE REPORT OLSON CREEK #2 REPORT FOR LUNDA, SMUSHKOV DATE Sep 09, 2014 DEPTH 7543.00000 PRESENT OPERATION CLEAN OUT/TAPPER MILL RUN TIME 24 HOURS YESTERDAY 7543.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9.625" @ 2023' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 7404.85' 37.50 279.07 6005.62' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" REED HYCA SKH1616H E197955 6X13 2023 7543 5520 84 1-1-CT-S-X-I-NO BHA 3 8.5" TAPPER MILL TSA3627 1X64 7543 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 7543' MW 9.5 VIS 60 PV 19 YP 19 FL 4.6 Gels 5/8/10 CL- 26000 FC 1/1 SOL 6.5 SD TR OIL 1/92.5 MBL 8.75 pH 10 Ca+ 60 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 9 @ TOOH 0 @ TOOH 2 TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) @ @ CONNECTION GAS HIGH - ETHANE (C-2) @ @ AVG - PROPANE (C-3) @ @ CURRENT - BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 2 PENTANE (C-5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 7543' = 90% SAND, 10% TUFFACEOUS SILTSTONE DAILY ACTIVITY SUMMARY TRIP OUT OF THE HOLE FROM 4455' TO 2023'. CIRCULATE BOTTOMS UP AND FLOW CHECK THE WELL. TRIP OUT OF THE HOLE FROM 2023' TO 888'. WORK THE BHA AND RACK BACK THE DRILL COLLARS. HOLD A PRE JOB SAFETY MEETING FOE MWD TOOLS. DOWN LOAD THE TOOL. LAY OUT THE DIRECTIONAL TOOLS. BREAK OUT THE BIT (NO BALLING NOTED) AND RACK BACK THE COLLARS. CLEAN THE RIG FLOOR AND BLOW DOWN THE KELLY. PULL THE WEAR BUSHING AND RIG UP THE TEST PUMP. DRAIN AND FLUSH THE STACK. HOLD A PRE JOB SAFETY MEETING ON TESTING THE BOPE AND TEST THE BOPE. RIG DOWN THE TEST EQUIPMENT AND BLOW THE CHOKE MANIFOLD AND SET THE WEAR BUSHING. LUBE THE CROWN, DRAW WORKS AND TOP DRIVE. CHECK A LEAK ON THE TOP DRIVE AND WAIT ON TOOLS. CLEAN THE RIG FLOOR. MAKE UP NEW BHA AND STRAP THE NEW BHA. HOLD A PRE JOB SAFETY MEETING ON PICKING UP THE BHA. RUN IN THE HOLE WITH TAPPER MILL TO 2680' - 1865' AND WORK THE SHOE AREA AT 43 RPM, 34779 TORQ, 482 PP @ 447 GPM (MIDNIGHT). CANRIG PERSONNEL ON BOARD BROWNE, BAKER + 2 SC DAILY COST $2985 REPORT BY LEES F. BROWNE JR. COOK INLET ENERGY DAILY WELLSITE REPORT OLSON CREEK #2 REPORT FOR LUNDA, SMUSHKOV DATE Sep 08, 2014 DEPTH 7543.00000 PRESENT OPERATION TRIP OUT TO TEST BOPE TIME 24 HOURS YESTERDAY 6821.00000 24 HOUR FOOTAGE 722 CASING INFORMATION 9.625"@ 2023' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 7404.85 37.50 279.07 6005.62 7311.02 37.71 278.48 5931.29 7213.22 36.07 278.03 5854.11 7117.65 37.78 278.18 5778.65 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" REED HYCA SKH1616M E197955 6X13 2023 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 193.8 @ 7399.00000 0.5 @ 7086.00000 103.2 107.84374 FT/HR SURFACE TORQUE 19 @ 7497.00000 0 @ SLIDE 15.6 19.74000 AMPS WEIGHT ON BIT 38 @ 7086.00000 0 @ SLIDE 7.0 6.29000 KLBS ROTARY RPM 75 @ 7344.00000 0 @ SLIDE 63.8 74.15000 RPM PUMP PRESSURE 3133 @ 7020.00000 1453 @ 7291.00000 2904.0 2996.30005 PSI DRILLING MUD REPORT DEPTH 7543' MW 9.4+ VIS 54 PV 19 YP 19 FL 4.2 Gels 5/7/10 CL- 26000 FC 1/1 SOL 6.5 SD tr OIL 1/92.5 MBL 8.75 pH 10 Ca+ 60 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 253 (COAL) @ 7323.00000 0 @ 7340.00000 32.5 TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) 49021 @ 7323.00000 96 @ 7339.00000 6078.0 CONNECTION GAS HIGH 11 ETHANE (C-2) 132 @ 7440.00000 0 @ 7340.00000 20.6 AVG 8 PROPANE (C-3) 23 @ 7431.00000 0 @ 7340.00000 1.3 CURRENT 11 BUTANE (C-4) 13 @ 7322.00000 0 @ 7340.00000 0.3 CURRENT BACKGROUND/AVG 0 TOOH PENTANE (C-5) 0 @ 7543.00000 0 @ 7543.00000 0.0 HYDROCARBON SHOWS NO GAS SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS SILTSTONE, TUFFACEOUS SANDSTONE, SAND, ASH, COAL, CARBONACEOUS SHALE PRESENT LITHOLOGY 7540' = 90% SAND, 10% TUFFACEOUS SANDSTONE DAILY ACTIVITY SUMMARY DRILL/SLIDE FORMATION FROM 6821' TO 7290'. CIRCULATE THE HOLE AND WORK ON MUD PUMP #2. DRILL/SLIDE FORMATION FROM 7290' TO 7543'. CIRCULATE AND TAKE A SURVEY. PUMP A HIGH VISCOSITY SWEEP AND START TO PULL OUT OF THE HOLE ON ELEVATORS FROM 7343. HOLE PULLED TIGHT AT 4455'. WORKED THE DRILL PIPE AND CIRCULATED BOTTOMS UP AND CONTINUED TO PULL OUT OF THE HOLE TO TEST BOP EQUIPMENT. CANRIG PERSONNEL ON BOARD BROWNE, BAKER + 2 SC DAILY COST 2985 REPORT BY LEES F. BROWNE JR. COOK INLET ENERGY DAILY WELLSITE REPORT OLSON CREEK #2 REPORT FOR LUNDA, SMUSHKOV DATE Sep 07, 2014 DEPTH 6821.00000 PRESENT OPERATION DRILLING TIME 24 HOURS YESTERDAY 6018.00000 24 HOUR FOOTAGE 803 CASING INFORMATION 9.625" @ 2023' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 6740.30' 37.00 278.33 5479.01' 6644.93' 37.34 280.17 5403.01' 6549.97' 37.14 281.02 5327.42' 6455.27' 37.45 281.26 5252.21' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" REED HYCA SKH1616M E197955 6X13 2023 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 187.3 @ 6435.00000 2.9 @ 6309.00000 104.2 86.11435 FT/HR SURFACE TORQUE 18 @ 6778.00000 0 @ 6627.00000 14.1 4.23000 AMPS WEIGHT ON BIT 35 @ 6336.00000 0 @ 6366.00000 6.9 9.95000 KLBS ROTARY RPM 93 @ 6034.00000 0 @ 6324.00000 72.2 1.65000 RPM PUMP PRESSURE 3204 @ 6483.00000 2282 @ 6022.00000 2886.6 3018.10010 PSI DRILLING MUD REPORT DEPTH 6836' MW 9.5 VIS 58 PV 19 YP 20 FL 4.4 Gels 6/9/11 CL- 27000 FC 1/1 SOL 6.5 SD tr OIL 1/92.5 MBL 8.75 pH 10 Ca+ 72 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 199 (COAL) @ 6758.00000 1 @ 6301.00000 40.1 TRIP GAS - CUTTING GAS @ @ WIPER GAS 26 @ 6019' CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 37883 @ 6427.00000 275 @ 6301.00000 7182.1 CONNECTION GAS HIGH 10 ETHANE (C-2) 131 @ 6758.00000 0 @ 6192.00000 20.2 AVG 3 PROPANE (C-3) 22 @ 6373.00000 0 @ 6496.00000 2.6 CURRENT 9 BUTANE (C-4) 9 @ 6419.00000 0 @ 6411.00000 0.1 CURRENT BACKGROUND/AVG 40 PENTANE (C-5) 0 @ 6821.00000 0 @ 6821.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS SILTSTONE, TUFFACEOUS SANDSTONE, COAL, CARBONACEOUS SHALE, SAND PRESENT LITHOLOGY 6820' = 100% TUFFACEOUS SILTSTONE DAILY ACTIVITY SUMMARY CIRCULATE BOTTOMS UP AT 4660' (DURING WIPER TRIP). PICK UP DRILL PIPE FROM 4729' TO 5275'. LAY OUT DRILL PIPE AND STRAP 21 JOINTS OF DRILL PIPE. PICK UP AND RUN IN THE HOLE FROM 5275' TO 5928'. WASH DOWN ONE STAND TO BOTTOM. DRILL/SLIDE FROM 6019' TO 6212'. TROUBLE SHOOT PRESSURE LOSS. DRILL/SLIDE FROM 6212' TO 6403'. CIRCULATE AND PUMP SUCTION AND DISCHARGE SCREENS FOR DEBRIS. DRILL/SLIDE FROM 6403' TO 6821' (MIDNIGHT) CANRIG PERSONNEL ON BOARD BROWNE, BAKER + 2 SC DAILY COST $3185 REPORT BY LEES F. BROWNE JR. COOK INLET ENERGY DAILY WELLSITE REPORT OLSON CREEK #2 REPORT FOR LUNDA, SMUSHKOV DATE Sep 06, 2014 DEPTH 6018.00000 PRESENT OPERATION WIPER TRIP TIME 24 HOURS YESTERDAY 4879.00000 24 HOUR FOOTAGE 1139' CASING INFORMATION 9.625" @ 2023' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 5880.95' 38.38 278.82 4796.76' 5691.28' 38.38 279.09 4647.96' 5596.16' 38.53 278.39 4573.47' 5501.96' 37.80 278.43 4499.41' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" REED HYCA SKH1616M E197955 6X13 2023 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 185.3 @ 4931.00000 7.1 @ 5260.00000 109.6 64.93854 FT/HR SURFACE TORQUE 14 @ 5855.00000 0 @ SLIDE 11.5 13.80000 AMPS WEIGHT ON BIT 13 @ 5329.00000 0 @ SLIDE 6.5 9.41000 KLBS ROTARY RPM 99 @ 4894.00000 1 @ SLIDE 80.8 92.03000 RPM PUMP PRESSURE 3014 @ 5941.00000 2118 @ 5355.00000 2677.6 2953.52002 PSI DRILLING MUD REPORT DEPTH 6018' MW 9.5 VIS 55 PV 18 YP 20 FL 4.4 Gels 8/10/12 CL- 28500 FC 1/1 SOL 6.5 SD TR OIL 1.5/92 MBL 7.5 pH 10 Ca+ 88 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 161 (COAL) @ 5904.00000 0 @ 5254.00000 35.1 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 30657 @ 5804.00000 198 @ 5253.00000 6590.7 CONNECTION GAS HIGH ETHANE (C-2) 119 @ 5549.00000 0 @ 5071.00000 20.4 AVG PROPANE (C-3) 22 @ 5086.00000 0 @ 5834.00000 0.4 CURRENT BUTANE (C-4) 0 @ 6018.00000 0 @ 6018.00000 0.0 CURRENT BACKGROUND/AVG PENTANE (C-5) 0 @ 6018.00000 0 @ 6018.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS SILTSTONE, TUFFACEOUS CLAYSTONE, TUFFACEOUS SANDSTONE, SAND, CARBONACEOUS SHALE, COAL PRESENT LITHOLOGY 6018' = 90% TUFFACEOUS SILTSTONE, 10% TUFFACEOUS CLAYSTONE DAILY ACTIVITY SUMMARY DRILL AND SLIDE FORMATION FROM 4879' TO 5734'. CIRCULATE BOTTOMS UP TO REPLACE THE SWAB ON MUD PUMP #2. LUBE AND SERVICE THE RIG, DRILL/SLIDE FROM 5734' TO 5018'. CIRCULATE BOTTOMS UP AND FLOW CHECK. WIPER TRIP FROM 6019' TO 5365'. CIRCULATE BOTTOM'S UP @ 5365' (TO CLEAN THE HOLE) WITH A MAXIMUM GAS KICK OF 23 UNITS. CANRIG PERSONNEL ON BOARD BROWNE, BAKER + 2 SC DAILY COST $3185 REPORT BY LEES F. BROWNE JR. COOK INLET ENERGY DAILY WELLSITE REPORT OLSON CREEK #2 REPORT FOR LUNDA, SMUSHKOV DATE Sep 05, 2014 DEPTH 4879.00000 PRESENT OPERATION DRILLING TIME 24 HOURS YESTERDAY 3641.00000 24 HOUR FOOTAGE 1238' CASING INFORMATION 9.625" @ 2023' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4740.90' 28.88 280.85 3903.20' 4645.29' 38.85 281.01 3828.50' 4545.52' 38.95 281.39 3751.24' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" REED HYCA SKH1616M E197955 6X13 2023 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 375.2 @ 3780.00000 8.8 @ 3941.00000 140.7 104.80010 FT/HR SURFACE TORQUE 11 @ 4810.00000 0 @ SLIDE 8.3 10.45000 AMPS WEIGHT ON BIT 24 @ 4785.00000 0 @ SLIDE 7.0 6.75000 KLBS ROTARY RPM 102 @ 4811.00000 1 @ SLIDE 65.3 81.99000 RPM PUMP PRESSURE 2573 @ 4680.00000 1936 @ 3684.00000 2299.5 2505.76001 PSI DRILLING MUD REPORT DEPTH 4879' MW 9.5 VIS 61 PV 17 YP 21 FL 4.8 Gels 8/10/12 CL- 34000 FC 1/1 SOL 6.5 SD TR OIL 1.5/92 MBL 7 pH 10.1 Ca+ 68 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 104 (COAL) @ 4878.00000 0 @ 4579.00000 23.9 TRIP GAS CUTTING GAS @ @ WIPER GAS 24 @ 4637' CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 19628 @ 4878.00000 170 @ 4388.00000 4275.5 CONNECTION GAS HIGH 7 ETHANE (C-2) 85 @ 3820.00000 0 @ 4627.00000 7.3 AVG 4 PROPANE (C-3) 0 @ 4879.00000 0 @ 4879.00000 0.0 CURRENT 2 BUTANE (C-4) 0 @ 4879.00000 0 @ 4879.00000 0.0 CURRENT BACKGROUND/AVG 20 PENTANE (C-5) 0 @ 4879.00000 0 @ 4879.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS SILTSTONE, TUFFACEOUS CLAYSTONE, TUFFACEOUS SANDSTONE, CARBONACEOUS SHALE, COAL PRESENT LITHOLOGY 4870' = COAL 70%, CARBONACEOUS SHALE 30% DAILY ACTIVITY SUMMARY DRILL/SLIDE FORMATION TO 4637'. CIRCULATE BOTTOMS UP AND WIPER TRIP ON ELEVATORS FROM 4637' TO 3180'. PICK UP DRILL PIPE FROM 3277' TO 4637'. TRIP WAS SLICK (NO PULL).WIPER GAS WAS 24 UNITS. DRILL/SLIDE FORMATION FROM 4637' TO 4879'. CANRIG PERSONNEL ON BOARD BROWNE, BAKER + 2 SC DAILY COST $3185 REPORT BY LEES F. BROWNE JR. COOK INLET ENERGY DAILY WELLSITE REPORT OLSON CREEK #2 REPORT FOR LUNDA, SMUSHKOV DATE Sep 04, 2014 DEPTH 3641.00000 PRESENT OPERATION DRILLING TIME 24 HOURS YESTERDAY 2216.00000 24 HOUR FOOTAGE 1425' CASING INFORMATION 9.625" @ 2023' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 3502.35' 37.08 279.33 2930.11' 3407.57' 37.08 278.71 2854.49' 3313.09' 36.14 278.35 2778.66' 3218.51' 35.75 278.14 2702.09' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5 RH SKH1616M E197955 6X13 2023 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 850.0 @ 2256.00000 3.7 @ 3166.00000 159.9 138.67488 FT/HR SURFACE TORQUE 8 @ 3579.00000 0 @ 2509.00000 5.7 7.16000 AMPS WEIGHT ON BIT 58 @ 3166.00000 0 @ 2248.00000 5.4 8.54000 KLBS ROTARY RPM 82 @ 2798.00000 0 @ 2506.00000 63.6 73.99000 RPM PUMP PRESSURE 2324 @ 3159.00000 1597 @ 3262.00000 2081.0 1983.28003 PSI DRILLING MUD REPORT DEPTH 3641' MW 9.2+ VIS 60 PV 11 YP 17 FL 4 Gels 8/9/11 CL- 41000 FC 1/1 SOL 5 SD 0.25 OIL TR/95 MBL 4 pH 10 Ca+ 60 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 39 (COAL) @ 3108.00000 0 @ 2690.00000 9.2 TRIP GAS - CUTTING GAS @ @ WIPER GAS 11 @ 3260' CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 8091 @ 3108.00000 80 @ 2689.00000 1642.0 CONNECTION GAS HIGH 0 ETHANE (C-2) 68 @ 2787.00000 0 @ 3514.00000 6.2 AVG 0 PROPANE (C-3) 0 @ 3641.00000 0 @ 3641.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 3641.00000 0 @ 3641.00000 0.0 CURRENT BACKGROUND/AVG 9 PENTANE (C-5) 0 @ 3641.00000 0 @ 3641.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS SILTSTONE, TUFFACEOUS CLAYSTONE, TUFFACEOUS SANDSTONE, CARBON SHALE, COAL PRESENT LITHOLOGY 3640' = 100% TUFFACEOUS SILTSTONE DAILY ACTIVITY SUMMARY DRILL FORMATION FROM 2216' TO 2596'. CIRCULATE AND CONDITION THE HOLE WHILE CHANGING OUT THE SWAB ON MUD PUMP #2. DRILL FROM 2596' TO 3260'. BACK REAM 2 STANDS AND WIPER TRIP ON ELEVATORS FROM 3072' TO 1948'. PICK UP DRILL PIPE AND TRIP IN THE HOLE FROM 1948' TO 3260'. WIPER GAS WAS 11 UNITS. PROPER FILL ON TRIP. SLIGHT OVER PULL AT 2772' (COAL). DRILL FROM 3260' TO 3641' (MIDNIGHT). CANRIG PERSONNEL ON BOARD BROWNE, BAKER + 2 SC DAILY COST $3185 REPORT BY LEES F BROWNE JR. COOK INLET ENERGY DAILY WELLSITE REPORT OLSON CREEK #2 REPORT FOR LUNDA, SMUSHKOV DATE Sep 03, 2014 DEPTH 2216.00000 PRESENT OPERATION DRILLING TIME 24 HOURS YESTERDAY 2023.00000 24 HOUR FOOTAGE 193' CASING INFORMATION 9.625" @ 2023' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2217' 46.34 277.67 1888.91' 2076.55' 49.05 278.53 1825.49' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5 RH SKH1616M E197955 6X13 2023 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 260.6 @ 2211.00000 2.6 @ 2026.00000 129.1 141.84000 FT/HR SURFACE TORQUE 6 @ 2024.00000 4 @ SLIDE 4.1 0.00000 AMPS WEIGHT ON BIT 19 @ 2023.00000 1 @ SLIDE 3.8 3.98000 KLBS ROTARY RPM 70 @ 2166.00000 32 @ SLIDE 52.0 0.00000 RPM PUMP PRESSURE 1964 @ 2181.00000 988 @ 2043.00000 1634.4 1950.32996 PSI DRILLING MUD REPORT DEPTH 2215' MW 9.0 VIS 52 PV 9 YP 15 FL 5.8 Gels 6/8/10 CL- 32000 FC 1/1 SOL 4 SD - OIL TR/96 MBL 6 pH 10.2 Ca+ 60 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 9 @ 2116.00000 0 @ 2040.00000 3.4 TRIP GAS 2 @ 2023' CUTTING GAS 0 @ 2216.00000 0 @ 2216.00000 0.0 WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 1546 @ 2116.00000 34 @ 2042.00000 535.8 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 2216.00000 0 @ 2216.00000 0.0 AVG 0 PROPANE (C-3) 0 @ 2216.00000 0 @ 2216.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 2216.00000 0 @ 2216.00000 0.0 CURRENT BACKGROUND/AVG 4 PENTANE (C-5) 0 @ 2216.00000 0 @ 2216.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS SILTSTONE, TUFFACEOUS CLAYSTONE, SAND, SANDSTONE, CARBON SHALE PRESENT LITHOLOGY 2210' = 70% TUFFACEOUS SILTSTONE, 20% TUFFACEOUS CLAYSTONE, 10% SAND DAILY ACTIVITY SUMMARY FINISH TESTING THE BOP EQUIPMENT. MAKE UP THE BHA TO 888'. TRIP IN THE HOLE WITH SINGLES FROM THE CATWALK FROM 888' TO 1927'. LUBE THE RIG, DRAW WORKS, CROWN AND TOP DRIVE. TRIP IN THE HOLE TO 1960'. RIG UP THE TEST PUMP TO THE CHOKE. HOLD A PRE JOB SAFETY MEETING. TEST THE CASING TO 3000 PSI FOR 30 MINUTES. RIG DOWN THE TEST PUMP AND DRILL OUT THE FLOAT EQUIPMENT AND 20' OF NEW HOLE. DISPLACE THE SPUD MUD. HOLD A PRE JOB SAFETY MEETING AND RUN A F.I.T TO 15 PPG EMW. RACK BACK 2 STANDS OF DRILL PIPE AND LOAD THE PIPE RACK AND STRAP THE NEW PIPE. PICK UP DRILL PIPE AND RACK BACK IN THE DERRICK. DRILL FORMATION FROM 2045' TO 2216' (MIDNIGHT) CANRIG PERSONNEL ON BOARD BROWNE, BAKER + 2 SC DAILY COST $3185 REPORT BY LEES F. BROWNE JR. COOK INLET ENERGY DAILY WELLSITE REPORT OLSON CREEK #2 REPORT FOR LUNDA, MANIACI DATE Sep 02, 2014 DEPTH 2023.00000 PRESENT OPERATION TESTING BOPE TIME 08:16:24 YESTERDAY 2023.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9.625" @ 2023' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 1963.94 49.43 278.11 1752.04 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 2023' MW 9.5 VIS 69 PV 21 YP 20 FL 8 Gels 9/13/16 CL- 400 FC 1/- SOL 5 SD 0.75 OIL 0/95 MBL 18 pH 9 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) @ @ CONNECTION GAS HIGH - ETHANE (C-2) @ @ AVG - PROPANE (C-3) @ @ CURRENT - BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS NO FLUID CIRCULATED THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 100% CEMENT PRESENT LITHOLOGY 100% CEMENT DAILY ACTIVITY SUMMARY CHANGE LOWER RAMS TO 2 7/8 X 5 UBR. NIPPLE UP RISER AND FLOWLINE. RIG UP CAT WALK AND BEAVER SLIDE. RIG UP TEST UNIT. BUILD MUD IN PITS. HOLD A PRE JOB SAFETY MEETING ON TESTING BOPE. START TESTING THE BOPE. CANRIG PERSONNEL ON BOARD BROWNE, BAKER + 2 SC DAILY COST $3185 REPORT BY LEES F. BROWNE JR. COOK INLET ENERGY DAILY WELLSITE REPORT OLSON CREEK #2 REPORT FOR MANIACI, SMUSHKOV DATE Sep 01, 2014 DEPTH 2023.00000 PRESENT OPERATION NIPPLE UP TIME 24 HOURS YESTERDAY 2023.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9.625" @ 2023' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 1963.94 49.43 278.11 1752.04 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 2023' MW 9.5 VIS 69 PV 21 YP 20 FL 8 Gels 9/13/16 CL- 400 FC 1/- SOL 5 SD 0.75 OIL 0/95 MBL 18 pH 9 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ @ CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG PENTANE (C-5) @ @ HYDROCARBON SHOWS NO FLUIDS CIRCULATED THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 100% CEMENT PRESENT LITHOLOGY 100% CEMENT DAILY ACTIVITY SUMMARY NIPPLE DOWN RISER, DSA, KNIFE VALVE, ANNULAR AND DRESSER SLEEVE. CUT CASGING AT THE CONDUCTOR AND CASING WELD ON THE WELL HEAD. PREP CASING AND CONDUCTOR AND WELL HEAD ON. CLEAN THE MUD PITS. NIPPLE UP THE CHOKE LINE. SET THE LOWER RAMS, BLIND RAMS AND UPPER PIPES. CHOKE HCR AND MANUAL. KILL HCR AND MANUAL AND SET ANNULAR. CANRIG PERSONNEL ON BOARD BROWNE, BAKER + 2 SC DAILY COST $3185 REPORT BY LEES F. BROWNE JR. COOK INLET ENERGY DAILY WELLSITE REPORT OLSON CREEK #2 REPORT FOR MANIACI, SMUSHKOV DATE Sep 31, 2014 DEPTH 2023.00000 PRESENT OPERATION NIPPLE DOWN DIVERTER TIME 24 HOURS YESTERDAY 2023.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 9.625" @ 2023' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 1963.94 49.43 278.11 1752.04 1904.20 49.80 278.31 1713.33 1809.03 47.58 278.06 1650.51 1714.72 47.37 278.39 1586.77 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 2023' MW 9.5 VIS 67 PV 21 YP 19 FL 8 Gels 8/14/16 CL- 400 FC 1/- SOL 5 SD 0.75 OIL 0/95 MBL 18 pH 9 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 3 @ 2023' 0 @ TIH 1 TRIP GAS 3 @ 2023' CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C-1) @ @ CONNECTION GAS HIGH - ETHANE (C-2) @ @ AVG - PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY 100% CEMENT PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY FINISH RIGGING UP CASING TOOLS. RUN BAKER LOCK FLOAT AND SHOE TRACK. RUN 9 5/8" CASING TO 2023'. CIRCULATE 8 B/M AT 130 PSI. TRIP GAS WAS THREE UNITS. RIG UP CEMENT HEAD. HOLD A PRE JOB SAFETY MEETING CONCERNING CEMENTING. CEMENT THE CASING AND WAIT ON THE CEMENT. NO LOSSES WHILE CIRCULATING AND NO LOSSES DURING THE CEMENT JOB. NIPPLE DOWN THE DIVERTER LINE, ANNULAR KNIFE VALVE, DSA AND CUT THE CASING. CANRIG PERSONNEL ON BOARD BROWNE, BAKER + 2 SC DAILY COST $3185 REPORT BY LEES F. BROWNE JR. COOK INLET ENERGY DAILY WELLSITE REPORT OLSON CREEK #2 REPORT FOR SMUSHKOV, JONES DATE Aug 30, 2014 DEPTH 2023.00000 PRESENT OPERATION PREP TO RUN SURFACE CASING TIME 24 HOURS YESTERDAY 1581.00000 24 HOUR FOOTAGE 442' CASING INFORMATION 20" @ 90' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 1963.94 49.43 278.11 1752.04 1904.20 49.80 278.31 1713.33 1809.03 47.58 278.06 1650.51 1714.72 47.37 278.39 1586.77 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 12.25" HALLIBURTON ROLLER 5231971 3X20 117' 2023' 1906 28.5 3-3-WT-A-E-I-N TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 222.2 @ 1644.00000 20.8 @ 1696.00000 121.3 87.08709 FT/HR SURFACE TORQUE 5 @ 1825.00000 0 @ SLIDE 2.9 5.03000 AMPS WEIGHT ON BIT 28 @ 1616.00000 6 @ SLIDE 16.9 19.76000 KLBS ROTARY RPM 71 @ 1959.00000 1 @ SLIDE 45.0 69.52000 RPM PUMP PRESSURE 1982 @ 2005.00000 1513 @ 1635.00000 1826.9 1930.56995 PSI DRILLING MUD REPORT DEPTH 2023' MW 9.5 VIS 67 PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 35 (SAND) @ 1650.00000 1 @ 1858.00000 7.7 TRIP GAS - CUTTING GAS @ @ WIPER GAS 7 @ 2023' CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 6525 @ 1649.00000 165 @ 1692.00000 1425.6 CONNECTION GAS HIGH 0 ETHANE (C-2) 28 @ 1880.00000 0 @ 1931.00000 2.7 AVG 0 PROPANE (C-3) 5 @ 1582.00000 0 @ 1590.00000 0.1 CURRENT 0 BUTANE (C-4) 0 @ 2023.00000 0 @ 2023.00000 0.0 CURRENT BACKGROUND/AVG 0 PENTANE (C-5) 0 @ 2023.00000 0 @ 2023.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS CLAYSTONE, SAND, CARBONACEOUS SHALE, COAL PRESENT LITHOLOGY 2023' = 100% TUFFACEOUS CLAYSTONE DAILY ACTIVITY SUMMARY CONTINUE TO CLEAN OUT THE POSSUM BELLY AND FLOW LINE OF PACKED OFF CUTTINGS. DRILL FROM 1581' TO 2023' (CASING POINT). CIRCULATE BOTTOM'S UP TWICE AND BACK REAM OUT OF THE HOLE TO 220' AT 650 GPM/60 RPM. TRIP IN THE HOLE FROM 220' TO 2023'. WORK TIGHT SPOTS AT 1870' (COAL). CIRCULATE BOTTOM'S UP TWICE AT 2023'. WIPER GAS WAS 7 UNITS. OBSERVE A 15 MINUTE FLOW CHECK AND PUMP A 20 BBL/1.5 OVER SWEEP. TRIP OUT OF THE HOLE ON ELEVATORS FROM 2023' TO BHA. WORK THE BHA AND LAY DOWN THE DIRECTIONAL TOOLS. DRAIN THE MOTOR AND BRAKE THE BIT. CLEAN THE RIG FLOOR AND LAY DOWN UNWANTED TOOLS FROM THE RIG FLOOR. PICK UP CENTRALIZERS AND READY THE RIG FLOOR FOR THE CASING RUN. HOLD A PRE JOB SAFETY MEETING AND RIG UP THE CASING TOOLS. CANRIG PERSONNEL ON BOARD BROWNE, BAKER + 2 SC DAILY COST $3185 REPORT BY LEES F. BROWNE JR. COOK INLET ENERGY DAILY WELLSITE REPORT OLSON CREEK #2 REPORT FOR SMUSHKOV, JONES DATE Aug 29, 2014 DEPTH 1581.00000 PRESENT OPERATION WORK TO CLEAR FLOW LINE OF CUTTINGS PACK OFF TIME 24 HOURS YESTERDAY 405.00000 24 HOUR FOOTAGE 1176 CASING INFORMATION 20" @ 90' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 1048.58 18.99 280.03 1037.42 951.98 15.84 280.95 945.25 854.00 14.30 281.01 850.64 759.47 9.12 280.53 758.12 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 12.25" HALLIBURTON ROLLER 5231971 3X20 117' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 891.3 @ 1392.00000 1.1 @ 727.00000 135.1 210.38960 FT/HR SURFACE TORQUE 4 @ 1579.00000 SLIDE @ 1001.00000 1.2 4.06000 AMPS WEIGHT ON BIT 22 @ 1137.00000 SLIDE @ 931.00000 10.7 17.32000 KLBS ROTARY RPM 75 @ 405.00000 SLIDE @ 1421.00000 31.7 65.61000 RPM PUMP PRESSURE 1892 @ 1578.00000 911 @ 468.00000 1352.9 1870.16003 PSI DRILLING MUD REPORT DEPTH 1581' MW 9.1 VIS 75 PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 35 @ 1391.00000 0 @ 468.00000 4.3 TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 7046 @ 1391.00000 19 @ 468.00000 810.7 CONNECTION GAS HIGH 0 ETHANE (C-2) 59 @ 681.00000 0 @ 1383.00000 3.9 AVG 0 PROPANE (C-3) 14 @ 831.00000 0 @ 1566.00000 0.2 CURRENT 0 BUTANE (C-4) 0 @ 1581.00000 0 @ 1581.00000 0.0 CURRENT BACKGROUND/AVG 0 BYPASS SHAKER PENTANE (C-5) 0 @ 1581.00000 0 @ 1581.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TUFFACEOUS CLAYSTONE, COAL, CARBONACEOUS SHALE, SAND PRESENT LITHOLOGY 1580' = 50% TUFFACEOUS CLAYSTONE, 40% CARBONACEOUS SHALE, 10% COAL DAILY ACTIVITY SUMMARY FINISH WORKING ON BOSS GRINDER. DRILL FROM 404' TO 1000' @ 650 GPM, 1350 PSI. CIRCULATE AND WAIT ON BOSS UNIT. DRILL/SLIDE FROM 1000' TO 1202'. LUBE TOP DRIVE, DRAW TOOL AND CROWN. DRILL/SLIDE FROM 1202' TO 1581'. POSSUM BELLY AND SHAKERS PACKED OFF WITH CUTTINGS, CLEAN POSSUM BELLY AND SHAKERS AND WORK THE DRILL PIPE AT MIDNIGHT. CANRIG PERSONNEL ON BOARD BROWNE, BAKER + 2 SC DAILY COST $3185 REPORT BY LEES F. BROWNE JR. COOK INLET ENERGY DAILY WELLSITE REPORT OLSON CREEK #2 REPORT FOR SMUSHKOV, JONES DATE Aug 28, 2014 DEPTH 405.00000 PRESENT OPERATION WORK ON BOS UNIT GRINDER TIME 24 HOURS YESTERDAY 116.00000 24 HOUR FOOTAGE 289' CASING INFORMATION 20" @ 154' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 1 12.25" HAALLIBURTON/ROLLER 5231971 3X20 117 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 591.9 @ 185.00000 1.2 @ 372.00000 118.1 73.60379 FT/HR SURFACE TORQUE 2 @ 378.00000 0 @ 157.00000 1.2 2.04000 AMPS WEIGHT ON BIT 109 @ 155.00000 0 @ 402.00000 6.2 11.37000 KLBS ROTARY RPM 80 @ 294.00000 47 @ 158.00000 56.5 75.38000 RPM PUMP PRESSURE 1286 @ 385.00000 813 @ 157.00000 967.1 1278.56006 PSI DRILLING MUD REPORT DEPTH 405' MW 8.9 VIS 70 PV 22 YP 24 FL 12 Gels 9/17/22 CL- 400 FC 2/- SOL 2 SD - OIL 0/98 MBL 24 pH 9.7 Ca+ 120 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 2 @ 289.00000 0 @ 349.00000 0.4 TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 359 @ 289.00000 23 @ 320.00000 70.0 CONNECTION GAS HIGH 0 ETHANE (C-2) 21 @ 195.00000 0 @ 167.00000 1.9 AVG 0 PROPANE (C-3) 0 @ 405.00000 0 @ 405.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 405.00000 0 @ 405.00000 0.0 CURRENT BACKGROUND/AVG 0 PENTANE (C-5) 0 @ 405.00000 0 @ 405.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SAND, SANDSTONE, TUFFACEOUS SILTSTONE, CARBON SHALE, CONGLOMERATE SAND PRESENT LITHOLOGY 405' = CARBON SHALE, SAND, TUFFACEOUS SILTSTONE DAILY ACTIVITY SUMMARY RIG REPAIR - TROUBLESHOOT AND REPAIR FOOT THROTTLE ON RIG FLOOR. PICK UP COLLAR SLIPS AND CLAMPS. CALIBRATE HALLIBURTON'S ENCODER. PICK UP 3 JOINTS OF 8" FLEX COLLARS. PRESSURE TEST MUD PUMPS AND LINES TO 3500 PSI. HOLD A PRE JOB SAFETY MEETING FOR PICKING UP TOOLS. PICK UP MUD MOTOR AND ADJUST TO 1.5 PICK UP TOOLS AND MWD TOOL. DRILL OUT CONDUCTOR PIPE TO 117'. DRILL FORMATION FROM 117' TO 249'. RACK BACK TWO STANDS OF HWDP AND PICK UP 8" FLEX COLLARS AND JARS. TRIP GAS WAS ZERO. DRILL FORMATION FROM 249' TO 405'. WAIT ON BOS TO FIX GRINDER. LAY OUT AND STRAP DRILL PIPE AND PICK UP DRILL PIPE. CANRIG PERSONNEL ON BOARD BROWNE, BAKER + 2 SC DAILY COST $3185 REPORT BY LEES F. BROWNE JR.