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Home My WebLink About214-137Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 5/10/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL FALLS CREEK 6 (PTD 214-137) GPT/PERF 4/14/2022 Please include current contact information if different from above. 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ůůƐĂŶĚƐůŝĞŝŶƚŚĞE/E/>,/<>h'ͲdzKE<'^WKK> ϯ͘ ZůŝŶĞ ϰ͘ dƵƌŶǁĞůůŽǀĞƌƚŽƉƌŽĚƵĐƚŝŽŶΘĨůŽǁƚĞƐƚǁĞůů ͲůŝŶĞWƌŽĐĞĚƵƌĞ;ŽŶƚŝŶŐĞŶĐǇŝĨǁĂƚĞƌŝƐĞŶĐŽƵŶƚĞƌĞĚĂĨƚĞƌƉĞƌĨŽƌĂƚŝŶŐͿ ϭ͘ /ĨĂŶǇǌŽŶĞƉƌŽĚƵĐĞƐƐĂŶĚĂŶĚͬŽƌǁĂƚĞƌŽƌŶĞĞĚƐŝƐŽůĂƚĞĚ͗ Ϯ͘ D/ZhͲ>ŝŶĞĂŶĚƉƌĞƐƐƵƌĞĐŽŶƚƌŽůĞƋƵŝƉŵĞŶƚ͘WdůƵďƌŝĐĂƚŽƌƚŽĂďŽǀĞDW^W͘ ϯ͘ Z/,ĂŶĚƐĞƚƉůƵŐĂďŽǀĞƚŚĞƉĞƌĨŽƌĂƚŝŽŶƐ͘ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ƐͲďƵŝůƚtĞůů^ĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚtĞůů^ĐŚĞŵĂƚŝĐ hƉĚĂƚĞĚďǇDϭϭͲϬϭͲϭϵ ^,Dd/ EŝŶŝůĐŚŝŬhŶŝƚ tĞůů͗&ĂůůƐƌĞĞŬηϲ Wd͗ϮϭϰͲϭϯϳ W/͗ϱϬͲϭϯϯͲϮϬϲϰϱͲϬϬ Wdсϲ͕ϬϬϬ͛Dͬϱ͕ϲϬϬ͛ds dсϵ͕ϬϲϬDͬϴ͕ϮϵϮ͛ds 5.% ¶ :HOOKHDGFRQQHFWLRQ´2WLV ^/E'd/> ^ŝǌĞdǇƉĞtƚ'ƌĂĚĞŽŶŶ͘/dŽƉƚŵ ϭϲ͟ŽŶĚƵĐƚŽƌϭϬϵyͲϱϲtĞůĚϭϲ͟^ƵƌĨϴϬΖ ϵͲϱͬϴΗ^ƵƌĨ͘ƐŐϰϬ>ͲϴϬdϴ͘ϴϯϱ͟^ƵƌĨϯ͕ϱϮϭ͛ ϱͲϭͬϮΗWƌŽĚĂƐŝŶŐϭϳWͲϭϭϬϰ͘ϴϵϮ͟^ƵƌĨϵ͕ϬϱϬ͛ dh/E' ϮͲϳͬϴ͟WƌŽĚƵĐƚŝŽŶϲ͘ϰ>ͲϴϬhͲϴƌĚϮ͘ϰϰϭ͟^ƵƌĨϰ͕ϭϯϬ͛ ´ ´ ´ +ROH ´ :t>Zzd/> EŽ͘Dds/ƚĞŵ ϭϭϱϮ͛ϭϱϮ͛/D ϮϭϲϮ͛ϭϲϮ͛^>dZDyyϱ^^^^sǁͬϮ͘ϯϭϮ͟ŽƌĞ/ ϯϰ͕Ϭϰϲ͛ϯ͕ϴϭϱ͛ĂŬĞƌ^>ͲϯWĂĐŬĞƌ ϰϰ͕ϭϯϬ͛ϯ͕ϴϵϮ͛tŝƌĞůŝŶĞƌĞͲĞŶƚƌǇŐƵŝĚĞ ϱϲ͕ϬϬϬ͛ϱ͕ϲϬϬ͛WŽƐŝͲ^ĞƚWůƵŐǁͬϭϬĨƚ͘ĐĞŵĞŶƚ 72&# ¶ WZ&KZd/KEd/> ^ĂŶĚƐdŽƉ ;DͿ ƚŵ ;DͿ dŽƉ ;dsͿ ƚŵ ;dsͿŵƚ'ƵŶ ^ŝǌĞ^W&^ƚĂƚƵƐĂƚĞ ůŐ ϱϴͬϱϴͬϱϵϰ͕Ϯϰϵ͛ 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Ϯ͛ ϲ /ƐŽůĂƚĞĚ ϭϭͬϮϵͬϮϬϭϰ dͲϲ dͲϱ dͲϮϬ dͲϭ ůŐϭϰϬ ůŐ ϳϬ ůŐ ϭϯϱ ůŐϵϬ ůŐϵϬ dͲϴ dͲϭ ůŐϱϴͬ ϱϴͬϱϵ ůŐϱϴͬ ϱϴͬϱϵ ůŐϲϬ ůŐϭϯϭ ůŐϭϯϰ dͲϯ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVE® '40V 0 6 2019 1. Operations Abandon LJ Plug Perforations Fracture Stimulate LJ Pull Tubing Li a down LJ Performed: Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: N2 ❑� 2. Operator Hilcorp Alaska, LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑✓ Exploratory ❑ Stratigraphic❑ Service ❑ 214-137 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-133-20645-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: FEE -PRIVATE, ADL 590 (TPH) ADL384314 (BHL) Falls Creek #6 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Ninilchik Field / Beluga & Tyonek Gas Pool 11. Present Well Condition Summary: Total Depth measured 9,060 feet Plugs measured 6,000 feet true vertical 8,292 feet Junk measured N/A feet Effective Depth measured 6,000 feet Packer measured 4,046 feet true vertical 5,600 feet true vertical 3,815 feet Casing Length Size MD ,ND - Burst Collapse Structural Conductor 80' 16" 80' - . 80' - - Surface 3,521' 9-5/8" 3,521' 3,337' - 5,750 psi 3,090 psi Intermediate Production 9,050' 5-1/2" 9,050' 8,284' 10,640 psi _ .7,480 psi Liner .. Perforation depth Measured depth See Attached Schematic - - True Vertical depth See Attached Schematic - - Tubing (size, grade, measured and true vertical depth) 2-7/8" 6.4# / L-80 4,130' MD 3,892' TVD Baker SABL-3 4,046' MD 3,815' ND Packers and SSSV (type, measured and true vertical depth) sLa mmr9-ret scsssv 162' MD 162' ND 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 80 0 20 111 Subsequent to operation: 0 215 14 24 107 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development p ❑ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas .r WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-308 & 319-414 Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: hilcoro.com _IKMMerno Authorized Signature: / - Date: J\IbU d I `� Contact Phone: 777-8420 Form 10-404 Revised 4/2017 `/`/ ✓ /� 5 .�<. ✓itsl.imS� NOV 0 8 209 Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date FCU -06 E -Line 1 50-133-20645-00-00 214-137 10/7/19 10/7/19 Daily Operations: 10/07/2019 - Monday PTW and JSA. Spot equipment Rig up lubricator. Had leak on bottom 0 -ring. Change oring. PT to 250 psi low and 3000 psi high. Well flowing 182K at 106 psi. RIH w/GPT tool and tie into OHL. Run correlation log and send to town. From 5980' (Tag depth) to 4800' was 80% to 90% fluid. From 4800' to 1900' was gas cut fluid POOH. RIH w/2"x18' Razor Low Swell HC, 6 spf, 60 deg phase and tie into OHL. Ran correlation log and sent to town. Town wanted to see a little more log. Ran another log and send to town. We were 6' deep so perf depths were changed to 4247' to 4265'. Spotted and fired gun w/104 psi at approx. 1515 hrs. Good indication of gun going off. After 5 min - 106 psi, 10 min - 101 psi, and 15 min - 103 psi flow 144K. About 1000' from,surface rate spiked to 138 psi at 386K rate. All shots fired. Gun was wet. RIH w/2"x16' Razor Low Swell HC, 6 spf, 60 deg phase and tie into HLB PNL Log. Ran correlation log and send to town. Get ok to perf from 4228'- 4244'w/105 psi flowing 169K. Spotted and fired gun. After 5 min - 248K at 111 psi, 10 min - 118K at 102 psi and 15 min - 144K at 103 psi, POOH. All shots fired. All shots fired and gun was wet. RIH w/2"x18' Razor Low Swell HC, 6 spf, 60 deg phase and tie into HLB PNL Log. Ran correlation log and send to town. Get ok to perf from 4201' to 4219' flowing 155.5K at 103.9 psi. Spotted and fired gun w/165k at 106.7 psi. After 5 min - 168.5K at 105.2 psi; 10 min - 130.8K at 102 psi. and 15 min - 106.1K at.102 55 psi. POOH. All shots fired and gun was wet. Rig down lubricator and turn well back over to the field. F tr g 145 6K at 103.5. Ninilchik Unit Well: Falls Creek #6 SCHEMATIC PTD: 214-137 itn mP�asw,�C API: 50-133-20645-00 16" 9-5/8" 8-1/2" Hole RKB = 18.60' IM - TOC jy 3,020' i G 5.5" .. Q. _ 6 'j PBTD = 6,000' MD / 5,600' TVD TD = 9,060 MD / 8,292' TVD Big 58/ 58A/59 Big 58/ 58A/59 Big 70 Big 90 Blg 90 Blg 135 Blg 140 T-1 T -1B T-5 T-6 T-8 T-20 CASING r1FTAll Size Type Wt Grade Conn. ID Top Btm 16" Conductor 109 X-56 Weld 16" Surf 80' 9-5/8" Surf. Csg 40 L-80 BTC 8.835" Surf 3,521' 5-1/2" Prod Casing 17 P-110 CDC 4.892" Surf 9,050' TUBING 2-7/8" Production 6.4 L-80 EUE-8rd 2.441" 1 Surf I 4,130' IMAM RY nr:TA11 No. MD TVD Item 1 152' 1 152' CIM 2 162' 162' SLB TRMAXX 5E SCSSSV W/2.312"Bore ID 3 4,046' 3,815' Baker SABL-3 Packer 4 4,130' 3,892' Wireline re-entry guide 5 6,000' 5,600' Posi-Set Plug w/10 ft. cement PFRPORATInN r1FTAll Sands Top Btm Top Btm Amt Gun SPF Status Date (MD) (MD) (TVD) (TVD) Size Big 58/58A/59 4,249' 4,262' 4,000' 4,01 2' 13 2' 6 Open 06/11/19 Big 58/58A/59 4201' 4,219' 3,957' 3,973' 71' 2' 6 Open 10/07/19 elg 58/58A/59 4,228' 4,244' 3,981' 3,996' 71' 2' 6 Open 10/07/19 Big 58/58A/59 41247' 41265' 3,999' 4,015' 71' 2' 6 Open 10/07/19 Big 70 0' 4,203' 4,222' 20' 2' 12 Open 06/22/15 Blg 90 8' 4,477' 4,486' 10' 2' 6 Open 06/06/19 Big 90 =5,524'5,558' 78' 4,733' 4,761' 30' 2' 12 Open 06/22/15 Blg 135 20' 5,053' 5,071' 20' 2' 12 Open 06/22/15 B1g140 8' 5,166' 5,197' 24' 2' 6 Open 12/20/14 T 1 6' 5,223' 5,241' 20' 2' 6 Open 12/19/14 5,589' 5,609' 5,225' 5,244' 20' 2' 6 Open 12/04/14 T -IB 5,695' 5,705' 5,322' 5,331' 10' 2' 6 Open 06/06/19 T-5 5,921' 5,942' 5,528' 5,547' 20' 2' 6 Open 04/15/19 T-6 6,018' 6,031'5,616' 5,628' 13' 2' 6 Isolated 12/04/14 6,066' 6,084' 5,660' 5,676' 18' 2'6 Isolated 12/04/14 T-8 6,302' 6,322' 5,874' 5,892' 20' 2' 6 Isolated 12/04/14 T-20 7.300' 7,354 6,782' 6,830' 50' 2' 6 1 Isolated 11/24/14 7,300' 7,350' 6,782' 6,830' 50' 2' 6 1 Isolated 11/29/14 Updated by DMA 11-01-19 Ha'„fp Ai;,A.- MA: DATE 10/25/2019 Debra Oudean Hilcorp Alaska, LLC 21 41 37 GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 3 1399 Tele: 907 777-8337 E-mail: doudean@hilcorp.com To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 FALLS CREEK -06 (214 - Halliburton TMD3D 5 SEP 2019 FCU -06 FALLS_CREEK_#6 TMD30_05SEP19 W13/2019 3:18 PM FALLS_CREEK_#6 TPg1D3D_05SEP79_img 5!/13s;''20193:17 Ph 1 FALLS_C.REEK_#6_TIVID3D05SEPI9 Rf12!20193:19PM Please include current contact information if different from above. RECEIVED WV 0 1 20N AOGCC PDF Document 2;231 KS TIFF Fife 4,736 K6 LAS File 11,227 K9 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: i "! �/ /Wl \ Date: I I I I I L I Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Riknq Alu.k..1.1A E-mail: doudean@hilcorp.com DATE 10/25/2019 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician �� 333 W 7th Ave Ste 100 NocE1VF® Anchorage, AK 99501 .. . , 1714 IFTel 1:14 POM -110 IF IM ,q ®�G2019 C Halliburton PRODUCTION PROFILE 26 JUN 2019 FCU -06 FC1.1-0+6_PPROF_261UN19_TOP OF ALL PE... 7123120191:01)PM LAS File 1,1176 KB FCU-06_PPROF 261UN19_DN30 02120191:09 PM LAS File 10,768 KB FCU-06_P'PROF 26 UN19_DNM 71'23/20191:0D PM, LAS File 10, 6 KB r' FCU-05_PP'ROF_26JUN19_img 7/23/201.91:40 Ph1 TIFF File 4,537 KB FCO -06 PPROF 261UN19_UP30 7123./'20141:04 PM LAS File 10,775 KB FCU-06PPBtOF_25)UN79_UFSD 6 23/201a 1:0 Pt Q L45 Fite 10,.1 +± KB FC11-06_PPROF_261UN19 7123,2019 1:01) P10 PDF Document 2,253 KB Please include current contact information if different from above. 214137 31400 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Ninilchik Field, Beluga and Tyonek Gas Pool, Fall Creek 6 Permit to Drill Number: 214-137 Sundry Number: 319-414 Dear Mr. York: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.mgcc.olaska.gov Enclosed is the approved application for the 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, Jst�i`el.ielowski Commissioner DATED this 1 3 day of September, 2019. 3BDMSLF/'-/SEP 16 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 W ULI. '` .;� a 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well p ❑ Operations shutdown El Suspend ❑ Perforate Q Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Nitrogen 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilomp Alaska, LLC Exploratory ❑ Development Q Stratigraphic ❑ Service ❑ 214-137 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-133-20645-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C0 701C Will planned perforations require a spacing exception? Yes❑ No ❑Q Falls Creek #6 9. Property Designation (Lease Number): 10. Field/Pool(s): FEE -PRIVATE, ADL 590 (TPH) ADL384314 (BHL) I Ninilchik Field / Beluga & Tyonek Gas Pool it. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9,060' 8,292' 8,959' 8,210' -1,355 psi 6,000' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16' 80' 80' Surface 3,521' 9-5/8" 3,521' 3,337' 5,750psi 3,090psi Intermediate Production 9,050' 5-1/2" 9,050' 81284' 10,640psi 7,480psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2-7/8" 6.4# / L-80 4,130' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker SABL-3 / SLB tubing -retrievable SGSSSV 4,046'/ 162' MD and 3,815'1 162' TVD 12. Attachments: Proposal Summary 0 Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Strati ra hic g p ❑ Development ❑Q Service ❑ 14. Estimated Date for 'S 15. Well Status after proposed work: Commencing Operations: September 16, 2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: So York 777-8345 Contact Name: Christina Twogood Authorized Title: Operations Manager!! Contact Email: CtwO ood hllCof .COr11 Contact Phone: 777-8443 f- Lt g L Authorized Sinatu Date: / (J j 1 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: I ` LAC L4 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMS SEP 16 2019 Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes ❑ No V Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 22, Cg S� orm 1 -403, evisetl 4/20171 Approved a p�c tiisly li 1�r I hh�rom the date of a Submit Formand p �approval. Attachments in Duplicate �1��9 1-A K liltwm Nuku. LU Well Prognosis Well: Falls Creek #6 Date: 9/5/2019 Well Name: Falls Creek #6 API Number: 50-133-20643-00-00 Current Status: Producing Gas We ` Leg: NA Estimated Start Date: September161*,�2019 Rig: E -Line Reg. Approval Req'd? 10-403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-137 First Call Engineer: Christina Twogood (907) 777-8443 (0) (907) 378-7323 (C) Second Call Engineer: Taylor Nasse (907) 777-8354 (0) (907) 903-0341 (C) AFE Number: Max. Expected BHP: 1,758 psi at 4,022' TVD (Based on normal gradient) Max. Possible Surface Pressure: —1,355 psi at 4,022' TVD (Based on expected BHP and gas gradient to surface (0.1 psi/ft)) Brief Well Summary Falls Creek #6 was drilled and completed in November 2014. In December 2014 the T-20 (two intervals), T-8, T-6 (two intervals), T-1 (two intervals) and Big 140 (two intervals) sands were perforated. In June 2015 the Big 135, Big 90 and Big 70 sands were perforated. In April 2019 the T-5 sand was perforated. In June 2019 the T-113, Big 90, and Big 58/58A/59 sands were perforated. The purpose of this work/sundry is to re-perf/add additional footage in the Bel 58/58A/59 sands. Notes Regarding Wellbore Condition • The well is currently producing 135 MCFD from the Beluga and Tyonek sands. Safety Concerns • Discuss Nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. • Consider tank placement based on wind direction and current weather forecast (venting Nitrogen during thisjob). • Ensure all crews are aware of stop job authority. E -Line Procedure 1. MIRU E -Line and pressure control equipment. PT lubricator to 250 psi Low / 3,000 psi High. 2. RIH with GPT tool and find fluid level. If fluid is over the depth of the new perfs, discuss using Nitrogen with the Operations Engineer. 3. If needed, RU Nitrogen Truck, pressure up on well and push water back into formation. Use GPT tool to confirm water level is below interval to perf. 4. RU 2-3/8" HC, 6 SPF, 602 phasing perf guns. U ❑ikarp Alaska. LU S. RIH and perforate the below interval: Well Prognosis Well: Falls Creek #6 Date: 9/5/2019 Zone Sand Top(MD) I Btm(MD) Top(TVD) Btm(TVD) I Amt Beluga BEL58/58A/59 1 ±4,201' 1 ±4,272' 1 ±3,957' 1 ±4,022' 71' a. Well may be shot flowing to minimize back pressure on the formation. If so, 2' long guns maybe shot first in the top of each interval to equalize pressure (to minimize the risk of being blown up hole) and then the remaining perfs will be shot. b. If well is not shot flowing, pressure up well to 1,400 psi before perforating. c. Proposed perfs also shown on the proposed schematic in red font. d. Final perfs tie-in sheet will be provided in the field for exact perf intervals. e. Make correlation pass and send log in to Operations Engineer, Reservoir Engineer and the Geologist. f. Use Gamma/CCL to correlate. g. Rule 2 of Conservation Order 701C defines the Ninilchik Beluga/Tyonek Gas Pool as the intervals common to and correlating between the measured depths of 1,555' and 9,035' in the Kalotsa No. 3 well. h. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run. i. Record 5, 10 and 15 minutes pressures after firing guns. 6. POOH. 7. RD E -Line. 8. Turn well over to production. E -Line Procedure (Contingency) 1. If these zones produce sand and/or water and need to be isolated. 2. MIRU E -Line and pressure control equipment. PT lubricator to 250 psi Low / 3,000 psi High. 3. RIH and set 3-1/2" Casing Patch or set 3-1/2" CIBP above the zone and dump 35' of cement on top of the plug. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. Standard Well Procedure — N2 Operations Ninilchik Unit SCHEMATIC Well: Falls Creek #6 PTD: 214-137 Nal x� �u API: 50-133-20645-00 RKB =18.60' TOC @ 3,020' 9-5/8" 8-1/2" Hole Big 58/ 58A/59 Big 70 Big 90 Big 90 Big 135 Big 140 T-1 T -IB T-5 T-6 T-8 T-20 55"c' 2^..twM PBTDV= 8,959' MSD / 8,210' TVD TO = 9,060 MD / 8,292' TVD CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16" Conductor 109 X-56 Weld 16" Surf 80' 9-5/8" Surf. Csg 40 L-80 BTC 8.835" Surf 3,521' 5-1/2" Prod Casing 17 P-110 CDC 4.892" Surf 9,050' TUBING 2-7/8" Production 6.4 L-80 I EUE-8rd 1 2.441" 1 Surf 1 4,130' JEWELRY DETAIL No. MD TVD Item 1 152' 152' CIM 2 162' 162' SLB TRMAXX 5E SCSSSV W/ 2.312" Bore ID 3 4,046' 3,815' Baker SABL-3 Packer 4 4,130' 3,892' Wireline re-entry guide 5 6,000' 5,604 Posi-Set Plug w/ 10 k. cement PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Gun Size SPF Status Date Big 58/58A/59 4,249' 4,262' 4,000' 4,012' 13 2' 6 Open 06/11/19 Big 70 4,470' 4,490' 4,203' 4,222' 20' 2' 12 Open 06/22/15 Big 90 4,768' 4,778' 4,477' 4,486' 16 2' 6 Open 06/06/19 Big 90 5,048' 5,078' 4,733' 4,761' 30' 2' 12 Open 06/22/15 Big 135 5,400' 5,420' 5,053' 5,071' 20' 2' 12 Open 06/22/15 Big 140 5,524' 5,558' 5,166' 5,197' 24' 2' 6 Open 12/20/14 T 5,586' 5,606' 5,223' 5,241' 20' 2' 6 Open 12/19/14 1 5,589' 5,609' 5,225' 5,244' 20' 2' 6 Open 12/04/14 T -IB 5,695' 5,705' 5,322' 5,331' 30' 2' 6 Open 06/06/19 T-5 5,921' 5,942' 5,528' 5,547' 20' 2' 6 Open 04/15/19 T-6 6,018' 6,031' 5,616' 5,628' 13' 2' 6 Isolated 12/04/14 6,066' 6,084' 5,660' 5,676' 18' 2' 6 Isolated 12/04/14 T-8 1 61302' 6,322' 5,874' 5,892' 20' 2' 6 Isolated 12/04/14 T-20 7.300' 7,350' 6,782' 6,830' S0' 2' 6 Isolated 11/24/14 11 7,306 7,350' 6,782' 6,830' 50' 2' 6 Isolated 11/29/14 Wellhead connection 4.5" Otis Updated by DMA 06-19-19 16" L{-; 8-1/2" Hole RKB = 18.60' 5 PROPOSED SCHEMATIC n n. L Toc 3,020' i i a Big 58/ 58A/59 _ -- Big 58/ - 58A/59 Big 70 Big 90 Big 90 Big 135 Big 140 T-1 T -1B T-5 T-6 T-8 -r T-20 t' PBTD = 8,959' MD / 8,210' TV D TO = 9,060 MD / 8,292' TVD CASING DETAIL Ninilchik Unit Well: Falls Creek #6 PTD: 214-137 API: 50-133-20645-00 Size Type Wt Grade Conn. ID Top Btm 16" Conductor109 162' %-56 Weld 16" Surf 80' 9-5/8" Surf. Csg 40 L-80 BTC 8.835" Surf 3,521' 5-1/2" Prod Casing 17 P-110 CDC 4.892" Surf 9,050' TUBING 2-7/8" Production 6.4 L-80 I EUE-8rd 1 2.441" Surf 4,130' JEWELRY DETAIL No. MD TVD Item 1 152' 152' CIM 2 162' 162' SLBTRMAXX5ESCSSSVw/2.312"Bore ID 3 4,046' 3,815' Baker SABL-3 Packer 4 4,130' 3,892' Wireline re-entry guide 5 6,000' 5,600' Posi-Set Plug w/ 10 ft. cement PERFORATION DFTAII Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Gun Size SPF Status Date Big 58/58A/59 4,249' 4,262' 4,000' 4,012' 13 2' 6 Open 06/11/19 Big 58/58A/59 ±4,201' ±4,272' ±3,957' ±4,022' ±71' 2' 6 TBD Proposed Big 70 4,470' 4,490' 4,203' 4,222' 20' 2' 12 Open 06/22/15 Big 90 4,768' 4,778' 4,477' 4,486' 10' 2' 6 Open 06/06/19 Big 90 5,048' 5,078' 4,733' 4,761' 30' 2' 12 Open 06/22/15 Big 135 5,400' 5,420' 5,053' 5,071' 20' 2' 12 Open 06/22/15 BIg140 5,524' 5,558' 5,166' 5,197' 24' 2' 6 Open 12/20/14 T-1 5,586' 5,606' 5,223' 5,241' 20' 2' 6 Open 12/19/14 5,589' 5,609' 5,225' 5,244' 20' 2' 6 Open 12/04/14 T-16 5,695' 5,705' 5,322' 5,331' 10' 2' 6 Open 06/06/19 T-5 5,921' 5,942' 5,528' 5,547' 20' 2' 6 Open 04/15/19 T-6 6,018' 6,031' 5,616' 5,628' 13' 2' 6 Isolated 12/04/14 6,066' 6,084' 5,660' 5,676' 18' 2' 6 Isolated 12/04/14 T-8 6,302' 6,322' 5,874' 5,892' 20' 2' 6 Isolated 12/04/14 T-20 7,300' 7,350' 6,782' 6,830' 50' 2' 6 Isolated 11/24/14 7,30D 7,354 6,782' 6,530' S0'1 2' 6 Isolated 11/29/14 Wellhead connection 4.5" Otis Updated by CMT 9/5/2019 STANDARD WELL PROCEDURE Illlcurp AlaAa. IAX NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre -job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4 -gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL vl Page 1 of 1 THE STATE Alaska Oil and Gas °fALASKA Conservation Commission GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Ninilchik Field, Beluga & Tyonek Gas Pool, Falls Creek 6 Permit to Drill Number: 214-137 Sundry Number: 319-308 Dear Mr. York: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the 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, C-P�� Daniel T. Seamount, Jr. Commissioner DATED this da of June, 2019. RSDMSjLYAJJUN 2 6 2019 ■ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 JUN 2 4 2019 AOGCC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Rednll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development F±1 • Stratigraphic ❑ Service ❑ 214-137 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-133-20645-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 701 C Will planned perforations require a spacing exception? Yes ❑ No Falls Creek #6 9. Property Designation (Lease Number): 10. Field/Pool(s): FEE -PRIVATE, ADL 590 (TPH) ADL384314 (BHL) I Ninilchik Field / Beluga & Tyonek Gas Pool it. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9,060' • 8,292' 8,959' 8,210'—2,183psi 6,000' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16' 80' 80' Surface 3,521' 9-5/8" 3,521' 3,337' 5,750psi 3,090psi Intermediate Production 9,050' 5-1/2" 9,050' 8,284' 10,640psi 7,480psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2-7/8" 6.4# / L-80 4,130' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker SABL-3 / SLB tubing -retrievable ScSSSV 4,0461 162' MD and 3,815'/ 162' TVD 12. Attachments: Proposal Summary w Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: July 10, 2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramerQhilcom.com ,�y'�. Contact Phone: 777-8420 l Authorized Signature:/ _/ Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 2)O/ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes EJ No El gB®MSi�f-MUN Z 6 2019 Spacing Exception Required? Yes ❑ No Subsequent Form Required: �•1.�-/ APPROVED BY Approved by, COMMISSIONER THE COMMISSION Date: (,/y/ /•/ ecl G1� /� n n JGJ A Submit Form and /VY,co'�m to -40 Revi� #!20 7 Approvetl application i�v�lir)"brp t o�l�ate of approval. Awa/3,��hments in Duplicate rJ IVVJ , ` 1 �;;,-x / 4 -Z5 -j/ Well Prognosis Well: Falls Creek #6 Date:6/19/2019 Well Name: Falls Creek #6 API Number: 50-133-20643-00 Current Status: Producing Leg: Tyonek Estimated Start Date: July 10, 2019 Rig: ±5,454' Reg. Approval Req'd? 10-403 Date Reg. Approval Rec'vd: BEL 132 Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-137 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (C) Second Call Engineer: Bo York (907) 777-8345 (0) (907) 727-9427 (C) AFE Number: BEL 58U ±4,168 ±4,177 Estimated Bottom Hole Pressure' Max. Possible Surface Pressure: Brief Well Summary —2,424' psi at 5,545' TVD —2,183 psi. Falls Creek #6 is currently producing 135 mcf from the Beluga and Tyonek sands. Objective of Work (Assumed 0.43 psi/ft gradient) (0.10 psi/ft gas gradient) The purpose of this work is to add additional sands -the T3, Bel 132, Bel 60, and Bel 58U to increase rate. E -Line Procedure 1. MIRU a -line and pressure control equipment. PT lubricator to 250 psi low/3,500 psi high. 2. Run GPT to determine fluid Level. IF fluid is above desired perf depths, consult with town. Otherwise go to step 3. 3. PU perf guns and RIH to depth and perforate the Tyonek and Beluga sands below. Make correlation pass and send log in to Operations Engineer, Reservoir Engineer and the Geologist. Note: Well may be shot flowing to minimize back pressure on the formation. If so, 2' long guns may be shot first in the top of each interval to equalize pressure (to minimize the risk of being blown up hole) and then the remaining perfs will be shot. Proposed Perforated Intervals Zone Sand Top(MD) Btm(MD) Top(TVD) Stm(TVD) Amt Tyonek T3 ±5,840' ±5,852' ±5,454' ±5,565' 12' Beluga BEL 132 ±5,325' ±5,331' ±4,985 ±4,991' 6' Beluga BEL60 ±4,319' ±4,338' ±4,478' ±4,065' 19' Beluga BEL 58U ±4,168 ±4,177 ±3,927' ±3,935 9' a. Proposed perfs also shown on the proposed schematic in red font. b. Use Gamma/CCL to correlate. c. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run. ✓� d. Nitrogen may be used to push water below intended perforations. Well Prognosis Well: Falls Creek #6 ❑ilwrn Alaska. LL Date: 6/19/2019 e. If a zone proves to be wet, a plug or patch may be set prior to perforating the next interval. f. Rule 2 of Conservation Order 701C defines the Ninilchik Beluga/Tyonek Gas Pool as the intervals common to and correlating between the measured depths of 1,555' and 9,035' in the Kalotsa No. 3 well. 4. POOH. 5. RD e -line. 6. Turn well over to production to test. Attachment: 1. Well Schematic 2. Proposed Wellbore Schematic 3. Nitrogen Form Ninilchik Unit Well: Falls Creek #6 11 SCHEMATIC PTD: 214-137 API: 50-133-20645-00 e.v Aln.ka, LLC RKB = 18.60' 8-1/2" Hole TOC @ 3,020' . 1 Big 58/ 58A/59 _ Big 70 Big 90 =Y Big 90 Big 135 Big 140 T-1 T -1B T-5 CASING DETAIL Size Type Wt Grade Conn. ID Top Btm 16" Conductor 109 X-56 Weld 16" Surf 80' 9-5/8" Surf. Csg 40 L-80 BTC 8.835" Surf 3,521' 5-1/2" Prod Casing 17 P-110 CDC 4.892" Surf 9,050' TUBING 2-7/8" Production 6.4 L-80 I EUE-8rd 1 2.441" 1 Surf 1 4,130' JEWELRY DETAIL No. MD TVD Item 1 152' 152' CIM 2 162' 162' SLB TRMAXX SE SCSSSV w/ 2.312" Bore ID 3 4,046' 3,815' Baker SABL-3 Packer 4 4,130' 3,892' Wireline re-entry guide 5 6,000' 5,600' Posi-Set Plug w/ 10 ft, cement PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Gun Size SPF Status Date Big 58/58A/59 4,249' 4,262' 4,000' 4,012' 13 2' 6 Open 06/11/19 Big 70 4,470' 4,490' 4,203' 4,222' 20' 2' 12 Open 06/22/15 Big 90 4,768' 4,778' 4,477' 4,486' 10' 2' 6 Open 06/06/19 Big 90 5,048' 5,078' 4,733' 4,761' 30' 2' 12 Open 06/22/15 Big 135 5,400' 5,420' 5,053' 5,071' 20' 2' 12 Open 06/22/15 Big 140 5,524' 5,558' 5,166' 5,197' 24' 2' 6 Open 12/20/14 5,586' 5,606' 5,223' 5,241' 20' 2' 6 Open 12/19/14 T-1 5,589' 5,609' 5,225' 5,244' 20' 2' 6 Open 12/04/14 T -1B 5,695' 5,705' 5,322' 5,331' 101 2' 6 Open 06/06/19 T-5 5,921' 5,942' 5,528' 5,547' 20' 2' 6 Open 04/15/19 6,018' 6,031' 5,616' 5,628' 13' 2' 6 Isolated 12/04/14 T-6 6,066' 6,084' 5,660' 5,676' 18' 2' 6 Isolated 12/04/14 T-8 6,302' 6,322' 5,874' 5,892' 20' 2' 6 Isolated 12/04/14 7,300' 7,350' 6,782' 6,830' S0' 2' 6 Isolated 11/24/14 T-20 7,3W 7,350' 6,782' 6,8301 50' 2' 6 Isolated 11/29/14 T-6 T-8 T-20 5.5' 1 _Q'-' tJ1 ----------------' PBTD = 8,959' MD / 8,210' TVD TD = 9,060 MD / 8,292' TVD Wellhead connection 4.5 " Otis Updated by DMA 06-19-19 K Ilileury AluaLn, LLC RKB = 18.60' 9-5/8" 8-1/2" Hole PROPOSED SCHEMATIC CASING DETAIL Ninilchik Unit Well: Falls Creek #6 PTD: 214-137 API: 50-133-20645-00 TUBING �s 2-7/8" Production 6.4 L-80 I EUE-8rd 1 2.441" 1 Surf I 4,130' r� c; JEWELRY DETAIL TOC 3,020' I BIg 58U BIg 58/ 58A/59 BIg 60 BIg 70 BIg 90 BIg 90 �- BIg 135 BIg 132 BIg 14( -- - T-1 T -1B - T-3 T-5 _= T-6 T-8 T-20 -�� PBTD = 8,959' MD / 8,210' TVD TD = 9,060 MD / 8,292' TVD No. Size Type Wt Grade Conn. ID Top atm 162' 16" Conductor 109 X-56 Weld 16" Surf 80' 3,892' 9-5/8" Surf. Csg 40 L-80 BTC 8.835" Surf 3,521' y; 5-1/2" Prod Casing 17 P-110 CDC 4.892" Surf 9,050' TUBING �s 2-7/8" Production 6.4 L-80 I EUE-8rd 1 2.441" 1 Surf I 4,130' r� c; JEWELRY DETAIL TOC 3,020' I BIg 58U BIg 58/ 58A/59 BIg 60 BIg 70 BIg 90 BIg 90 �- BIg 135 BIg 132 BIg 14( -- - T-1 T -1B - T-3 T-5 _= T-6 T-8 T-20 -�� PBTD = 8,959' MD / 8,210' TVD TD = 9,060 MD / 8,292' TVD No. MD TVD Item 1 152' 152' CIM 2 162' 162' SLB TRMAXX 5E SCSSSV w/ 2.312" Bore ID 3 4,046' 3,815' Baker SABL-3 Packer 4 4,13(Y 3,892' Wireline re-entry guide 5 6,000' 5,600' Posi-Set Plug w/ 30 ft. cement PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Gun Size SPF Status Date Big 58U ±4,168' ±4,177' ±3,927' 13,935' ±9' 2' 6 TBD Proposed BIg 58/58A/59 4,249' 4,262' 4,000' 4,012' 13 2' 6 Open 06/11/19 Big 60 ±4,319' ±4,338' ±4,478' ±4,065' ±19' 2' 6 TBD Proposed Big 70 4,470' 4,490' 4,203' 4,222' 20' 2' 12 Open 06/22/15 Big 90 4,768' 4,778' 4,477' 4,486' 10' 2' 6 Open 06/06/19 BIg 90 5,048' 5,078' 4,733' 4,761' 30' 2' 12 Open 06/22/15 BIg 132 ±5,325' ±5,331' 14,985' ±4,991' ±6' 2' 6 TBD Proposed BIg 135 5,400' 5,421' 5,053' 5,071' 20' 2' 12 Open 06/22/15 BIg140 5,524' 5,558' 5,166' 5,197' 24' 2' 6 Open 12/20/14 5,586' 5,606' 5,223' 5,241' 20' 2' 6 Open 12/19/14 7-1 5,589' 5,609' 5,225' 5,244' 20' 2' 6 Open 12/04/14 TAB 5,695' 5,705' 5,322' 5,331' 10' 2' 6 Open 06/06/19 T-3 ±5,840' ±5,852' ±5,454' ±5,565' ±12' 2' 6 TBD Proposed T-5 5,921' 5,942' 5,528' 5,547' 20' 2' 6 Open 04/15/19 6,018' 6,031' 5,616' 5,628' 13' 2' 6 Isolated 12/04/14 T-6 6,066' 6,084' 5,660' 5,676' 18' 2' 6 Isolated 12/04/14 T-8 61302' 6,322' 5,874' 5,892' 20' 2' 6 Isolated 12/04/14 7,300' 7,350' 6,782' 6,830' 50' 2' 6 Isolated 11/24/14 T-20 7,300' 7,350' 6,782' 6,830' 50' 2' 6 1 Isolated 11/29/14 Wellhead connection 4.5 "Otis Updated by DMA 06-19-19 STANDARD WELL PROCEDURE Hileorp Alaska, LIT NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre -Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4 -gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINALv1 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS JUN 21 2019 1. Operations Abandon LJ Plug PerforationsT3 Fracture Stimulate LJ Pull Tubing Aerations shutdown Li Performed: Suspend ❑ Perforate D Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Reddll ❑ ertorate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2. Operator Name: Hilcorp Alaska, LLC 4. Well Class Before Work: 5. Permit to Drill Number: Development ❑✓ Stratigraphic❑ Exploratory ❑ Service ❑ 214-137 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-133-20645-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: FEE -PRIVATE, ADL 590 (TPH) ADL384314 (BHL) Falls Creek #6 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Ninilchik Field / Beluga & Tyonek Gas Pool 11. Present Well Condition Summary: Total Depth measured 9,060 feet Plugs measured 6,000 feet true vertical 8,292 feet Junk measured N/A feet Effective Depth measured 8,959 feet Packer measured 4,046 feet true vertical 8,210 feet true vertical 3,815 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 80' 80' Surface 3,521' 9-5/8" 3,521' 3,337' 5,750 psi 3,090 psi Intermediate Production 9,050' 5-1/2" 9,050' 8,284' 10,640 psi 7,480 psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 2-7/8" 6.4# / L-80 4,130' MD 3,892' TVD Baker SABL-3 4,046' MD 3,815' TVD Packers and SSSV (type, measured and true vertical depth) SLB tubing- t scsssv 162' MD 162' TVD 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 129 0 20 108 Subsequent to operation:1 0 246 0 20 115 14. Attachments (required Per 20 AAC 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations Q Exploratory❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas WDSPL LJ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-122 Authorized Name: So York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer(dhilcom com L Authorized Signature: A Date: 2 t-5�....... Z t)(9 Contact Phone: 777-8420 Form 10-404 Revised 412017 xfl„�7 "'- (�'ZS '��( 3BDMS1P�t^JUN 2520 'bmit Original Only -/� Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Date FCU-06 E-Line 50-133-20645-00-00 214-137 T�411EVIT96 /11/19 Daily Operations: 04/15/2019 - Monday PTW and JSA. Rig lubricator up, PT to 250 psi low and 3500 psi high. Well flowing 124.7K at 109 psi. FL- 5,060',RIH W/ 2-3/8" X 20' HC, 6 SPF, 60 deg phase and tie into HLB OHL. Ran correlation log and send to town. Was as told to change perf depth from 5,922'-5,942' to 5,921'5,941'. Spotted gun from 5,921' to 5,941' and fired gun w/well flowing 126.4K at 108.8 psi, 5 min - 147.9K at 109.2 psi, 10 min - 192.7K at 111 psi and 15 min - 165.9K at 109.5 psi. POOH. All shots fired and Gun was wet. Rig down equipment, clean up work area and turn well over to field. 04/18/2019 - Thursday PTW and JSA. Rig up lubricator. PT to 250 low and 3,000 psi high. Well flowing 219.2K at 113 psi.;RIH with GPT and tie in to perf log. Sat down at 5,982'. Ran log up past last perfs. Well flowing at 222.1 at 110.6 psi. Found fluid level at 5,600'. POOH. Send logs to town. Rig down equip and turn well over to field. 06/06/2019 -Thursday PTW and JSA. Spot equipment and rig up lubricator. PT to 250 psi low and 3,500 psi high. Well flowing 165.6K at 110,1 psi. RIH w/GPT with well flowing 165K at 110 psi and correlated with OHL. Tag at bottom 5,982' and solid fluid level at 5,600'. Soupy/gas cut fluid in spots up to approx 2,300'. Run correlation log in 1" scale and 5" scale. Send to town and get ok to pert. POOH. Arm gun. RIH w/ 2" x 10' low swell Razor HC, 6 spf, 60 deg phase and tie into GPT log. Run correlation log and Send to town and was told to pert from 5,695' to 5,705' (Taylor Childers). Spotted and fired gun with well flowing 153k at 110 psi. 5 min - 166K at 110 psi,10 min -203K at 111 psi and 15 min - 187k at 111 psi. POOH. All shots fired. Gun was wet. Arm gun. RIH w/ 2" x 10' low swell Razor HC, 6 spf, 60 deg phase and tie into GPT log. Run correlation log and Send to town and was told to pert from 4,768' to 4,778' (Taylor Childers). Spotted and fired gun with well flowing 170k at 111.2 psi. 5 min - 333.3k at 128 psi, 10 min - 401.6k at 139 psi and 15 min - 391.9k at 130.2 psi. It was a steady climb from when we fired until approx. 12 min. POOH. All shots fired and gun. was wet. First gun fired at 1443 hrs. Second gun fired at 1647 hrs. Rig down lubricator and turn well. 06/11/2019-Tuesday PTW and JSA on PAX 1. Picked shed off well with crane and rig down. Moved to FC-4. PTW and JSA. Picked shed off well with crane. PTW and JSA. Spot equipment and rig up lubricator on FC-6. PT lubricator to 250 psi low and 3,500 psi high. Well flowing 255.7K at 114.1 psi. RIH w/GPT tool, tied into OHL and found solid fluid at 5,600'. Soapy/gas cut fluid up to 4,200'. Run log and send to town. POOH. RIH w/ 2" x 15' HC Razor, 6 spf, 60 deg phase and tie into GPT log. Ran correlation log and send to town. Re-ran log and send to town. Changed perf depths to 4,249' to 4,264'. Spotted and fired gun with well flowing 251k at 127 psi. After 5 min - 277k at 125 psi, 10 min - 277k at 121 psi and 15 min - 262.5k at 119.4 psi. POOH. All shots fired and gun was wet. Fired gun at 1442 hrs. Rig down lubricator and turn well over to field. Ninilchik Unit Well: Falls Creek #6 SCHEMATIC PTD: 214-137 Lc API: 50-133-20645-00 RKB =18.60' 9-5/8 8-1/2" Ilnle TOC @ 3,020' i BIg 58/ -58A/59 Big 70 Big 90 Big 90 Big 135 Big 140 T-1 T -1B T-5 PBTD = 8,959' MD / 8,210' TVD TD = 9,060 MD / 8,292' TVD CASINC DETAII Size Type Wt Grade Conn. ID Top Btm 16" Conductor 109 X-56 Weld 16" Surf 80' 9-5/8" Surf. Csg 40 L-80 BTC 8.835" Surf 3,521' 5-1/2" Prod Casing 17 P-110 CDC 4.892" Surf 9,050' TUBING 2-7/8" Production 6.4 L-80 EUE-8rd 2.441" Surf 4,130' IFWFI RV nFTAll DFRF(1RATInA1 n[TAII Sands MD TVD Item Btm (TVD) 52' 152' CIM R 62' 162' SLBTRMAXX5ESCSSSVw/2.312" BoreID 4.262' 046' 3,815' Baker SABL-3 Packer 2' 130' 3,892' Wireline re-entry guide BIg 70 000' 5,600' Posi-Set Plug w/ 10 h. cement DFRF(1RATInA1 n[TAII Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Gun Size SPF Status Date Big 58/58A/59 4.249 4.262' 4,000' 4,012' 13 2' 6 Open 06/11/19 BIg 70 4,474 4,490' 4,203 4,222' 20' 2' 12 Open 06/22/15 BIg 90 4,768' 4,778' 4,477' 4,486' 10' 2'6 Open 06/06/19 BIg 90 5,048' 5,078' 4,733' 4,761' 30' 2' 12 Open 06/22/15 Big 135 5,400' 5,420' 5,053' 5,071' 20' 2' 12 Open 06/22/15 Big 140 5,524' 5,558' 5,166' 5,197' 24' 2' 6 Open 12/20/14 T-1 5,586' 5,606' 5,223' 5,241' 20' 2' 6 Open 12/19/14 5,589' 5,609' 5,225' 5,244' 20' 2' 6 Open 12/04/14 TAB 5,695' 5,705' 5,322' 5,331' 10' 2' 6 Open 06/06/19 T-5 5,921' 5,942' 5,528' 5,547' 20' 2' 6 Open 04/15/19 T-6 6,018' 6,031' 5,616' 5,628' 13' 2' 6 Isolated 12/04/14 6,066' 6,084' 5,660' 5,676' 18' 2' 6 Isolated 12/04/14 T-8 6,302' 6,322' 5,874' 5,892' 20' 2' 6 Isolated 12/04/14 T-20 7�30d 7,350' 6,782' 6,830' 50' 2' 6 Isolated 11/24/14 7,300' 7,350' 6,782' 6,830' 90 2' 6 Isolated 11/29/14 Wellhead connection 4.5 " Otis Updated by DMA 06-19-19 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Ninilchik Field, Beluga & Tyonek Gas Pool, Falls Creek 6 Permit to Drill Number: 214-137 Sundry Number: 319-122 Dear Mr. York: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .aogcc.alaska.gov Enclosed is the approved application for the 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, Daniel T. Seamount, Jr. Commissioner DATED this?—" d7 ay of March, 2019. R13t)ms�" Nb 101019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25 280 =e �; MAR 11; 2Cli AOGCC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development ❑✓ Stratigraphic ❑ Service ❑ 214-137 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50133-20645-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 701C Will planned perforations require a spacing exception? YesFalls ❑ No Q Creek #6 9. Property Designation (Lease Number): 10. Field/Pool(s): _ FEE -PRIVATE ADL 590 (TPH) A131_384314 (BHL) I Ninilchik Field / Beluga & Tyonek Gas Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9,060' 8,292' 8,959' 8,210' -2,183psi 6,000' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16' 80' 80• Surface 3.521' 9.5/8^ 3,521' 3,337' 5,750psi 3,090psi Intermediate Production 9,050' 5-1/2" 9,050' 8,284' 10,640psi 7,480psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2-7/8" 6.4# / L-80 4,130' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker SABL-3 / SLB tubing -retrievable ScSSSV 4,046'/ 162' MD and 3,815'/ 162' TVD 12. Attachments: Proposal Summary Q Wellbore schematic 2_73 Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Q Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: March 28, 2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS O WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: So York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer@hilcoro com +.�Contact Phone: 777-8420 Authorized Signature: Date: � � ) l �v'"f.� t-0 1� COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3fq-12Z Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: 3BDMSL�' MAR 2 0 2019 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes No �Subsequent Form Required: � Y APPROVED BY Approved by: 312 COMMISSIONER THE COMMISSION Date: �-/ pP 1 �RI 9 1 (� Submit Form and Form 10-403 Revised 4/2017/""Approved a licat i v i 2 ^^RPP the date of approval. Alta hments it Duplicate 41 9 $.4.13 3/N/19 U Hik.rp Alaska, LL - Well Prognosis Well: Falls Creek #6 Date: 3/13/2019 Well Name: Falls Creek #6 API Number: 50-133-20643-00 Current Status: Producing Leg: Tyonek Estimated Start Date: March 28, 2019 Rig: ±51527' Reg. Approval Req'd? 10-403 Date Reg. Approval Rec'vd: T1B Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-137 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (C) Second Call Engineer: Taylor Nasse (907) 777-8354 (0) (907) 903-0341 (C) AFE Number: BEL 58/58A/59 ±4,201 ±4,272 Estimated Bottom Hole Pressure: Max. Possible Surface Pressure: Brief Well Summary —2,424' psi at 5,545' TVD ^2,183 psi. Falls Creek #6 is currently producing 135 mcf from the Beluga and Tyonek sands. Objective of Work (Assumed 0.43 psi/ft gradient) (0.10 psi/ft gas gradient) The purpose of this work is to add additional sands - the T5, TIB, Bel 58, Bel 58A, Bel 59 and BEL 90 to increase rate. E -Line Procedure 1. MIRU a -line and pressure control equipment. PT lubricator to 250 psi low/3,500 psi high. 2. Run GPT to determine fluid Level. IF fluid is above desired perf depths, consult with town. Otherwise go to step 3. 3. PU perf guns and RIH to depth and perforate the Tyonek and Beluga sands below. Make correlation pass and send log in to Operations Engineer, Reservoir Engineer and the Geologist. Note: Well may be shot flowing to minimize back pressure on the formation. If so, 2' long guns may be shot first in the top of each interval to equalize pressure (to minimize the risk of being blown up hole) and then the remaining perfs will be shot. Proposed Perforated Intervals Zone Sand Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt Tyonek T5 ±5,920' ±5,940' ±51527' ±5,545' 20' Tyonek T1B ±5,696' ±5,706' ±5,323 ±5,332' 10' Beluga BEL90 ±4,770' ±4,780' ±4,478' ±5,190' 10' Beluga BEL 58/58A/59 ±4,201 ±4,272 ±3,957' ±4,022 71' Proposed perfs also shown on the proposed schematic in red font. b. Use Gamma/CCL to correlate. c. Install Crystal gauges (or verify PTs are open to SCADA) before perforating. Record tubing pressures before and after each perforating run. Well Prognosis Well: Falls Creek #t6 Hilco p Alwkn. LG Date: 3/13/2019 d. Nitrogen may be used to push water below intended perforations. e. If a zone proves to be wet, a plug or patch may be set prior to perforating the next interval. f. Rule 2 of Conservation Order 701C defines the Ninilchik Belugarryonek Gas Pool as the intervals common to and correlating between the measured depths of 1,555' and 9,035' in the Kalotsa No. 3 well. 4. POOH. 5. RD a -line. 6. Turn well over to production to test. Attachment: 1. Well Schematic 2. Proposed Wellbore Schematic 3. Nitrogen Form R n.y,llvrhn. LLC RKB =18.60' TOC 3,020' 8-1/2" Hole BIg70 31g90 BIg135 Blg140 T-1 T-6 T-8 T-20 PBTD = 8,959' MD / 8,210' TVD TD = 9,060 MD / 8,292' TVD SCHEMATIC CASING DFTAII Ninilchik Unit Well: Falls Creek #6 PTD: 214-137 API: 50-133-20645-00 Size Type Wt Grade Conn. ID Top Btm 16" Conductor 109 X-56 Weld 16" Surf 80' 9-5/8" Surf. Csg 40 L-80 BTC 8.835" Surf 3,521' 5-1/2" Prod Casing 17 P-110 CDC 4.892" Surf 9,050' TUBING 2-7/8" Production 6.4 L-80 EUE-Srd 2.441" Surt 4,130' IFWFI RV DFTAII No. MD TVD Item 1 152' 152' CIM 2 162' 162' SLB TRMAXX 5E SCSSSV w/ 2.312" Bore ID 3 4,046' 3,815' Baker SABL-3 Packer 4 4,130' 3,892' Wireline re-entry guide 5 I 6,000' I 5,600' I Posi-Set Plug w/10 ft. cement PFRMPATIn Al nCTAII Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Gun Size SPF Status Date Big 70 4,470' 4,490' 4,203' 4,222' 20' 2" 12 Open 06/22/15 Big 90 5,048' 5,078' 4,733' 4,761' 30' 2" 12 Open 06/22/15 Big 135 5,400' 5,420' 5,053' 5,071' 20' 2" 12 Open 06/22/15 BIg140 5,524' 5,558' 5,166' 5,197' 24' 2" 6 Open 12/20/14 T 1 5,586' 5,606' 5,223' 5,241' 20' 2" 6 Open 12/19/14 5,589' 5,609' 5,225' 5,244' 20' 2" 6 0 en 12/04/14 T-6 6,018' 6,031' 5,616' 5,626 13' 2" 6 Isolated 12/04/14 6,066' 6,084' 5,660' 5,676' 18' 2" 6 Isolated 12/04/14 T-8 6,302' 6,322' 5,874' 5,892' 20' 2" 6 Isolated 12/04/14 T-20 7.300' 7,350' 6,782' 6,830' 50' 2" 6 Isolated 11/24/14 7,300' 7,350' 6,782' 6,830' S0' 2" 6 Isolated 11/29/14 Wellhead connection 4.5"Otis Updated by DMA 07-06-15 Ninilchik Unit WellPROPOSED SCHEMATIC PTD: 214 -Balls eek#6 PTD: 214-137 H kmP �„k, ,,, API: 50-133-20645-00 16" 9-5/8" 8-1/2" Hole RKB =18.60' 5 TOC Q 3,020' BIg 58/ �- 58A/59 Big 90 BIg70 = BIg90 Blg135 BIg140 T-1 PBTD = 8,959' MD / 8,210' TVD TD = 9,060 MD / 8,292' TVD T-18 T-5 T-6 T-8 T-20 CASING DETAII Size Type Wt Grade Conn. ID TOD Btm 16" Conductor 109 X-56 Weld 16" Surf 80' 9-5/8" Surf. Csg 40 L-80 BTC 8.835" Surf 3,521' 5-1/2" Prod Casing 17 P-110 CDC 4.892" Surf 9,054 TUBING 2-7/8" Production 6.4 L-80 EUE-8rd 2.441" Sufi 4,130' IFWFI RV nFTAII No. Top (MD) Btm (MD) Item 1 Amt Gun Size CIM 2 Date M3,815' SLB TRMAXX 5E SCSSSV w/ 2.312" Bore ID 3 ±3,957' ' Baker SABL-3 Packer 4 12 TBD Wireline re-entry guide 5 ±4,770' ' Posi-Set Plug w/ 30 ft. cement PFPF0PATllln1 n[TAII Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Gun Size SPF Status Date Big 58/58A/59 ±4,201 ±4,272 ±3,957' ±4,022 71' 2" 12 TBD Proposed Big 90 ±4,770' ±4,780• ±4,478' ±5,190' 10' 2" 12 TBD Proposed Big 70 4,470' 4,490' 4,203' 4,222' 20' 2" 12 Open 06/22/15 Big 90 5,048' 5,078' 4,733' 4,761' 30' 2" 12 Open 06/22/15 Big 135 5,400' 5,420' 5,053' 5,071' 20' 2" 12 Open 06/22/15 BIg140 5,524' 5,558' 5,166' 5,197' 24' 2" 6 Open 12/20/14 T-1 5,586' 5,606' 5,223' 5,241' 20' 2" 6 Open 12/19/14 5,589' 5,609' 5,225' 5,244' 20' 2" 6 Open 12/04/14 T-18 ±5,696 ±5,706' ±5,323 ±5,332' 30' 2" 12 TBD Pro osed T-5 ±5,920 ±5,940' ±5,527' ±5,545' 20' 2" 12 TBD Proposed T-6 6,018' 6,031' 5,616' 5,628' 13' 2" 6 Isolated 12/04/14 6,066' 6,084' 5,660' 5,676' 18' 2" 6 Isolated 12/04/14 1-8 6,302' 6,322' 5,874' 5,892' 20' 2" 6 Isolated 12/04/14 T-20 7.300' 7,350' 6,782' 6,830' 50' 2" 6 Isolated 11/24/14 7,300' 7,350' 6,782' 6,830' 50' 2" 6 Isolated 11/29/14 Wellhead connection 4.5 " Otis Updated by DMA 03-13-19 STANDARD WELL PROCEDURE Ililcurp Alaska, LLC NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre -Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4 -gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL vl Page 1 of 1 STATE OF ALASKA • Ar_.,SKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate LI Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate ❑' Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill 0 .irforate New Pool ❑ Repair Well 0 Re-enter Susp Well 0 Other: 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 2 Exploratory ❑ 214-137 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-133-20645-00 7.Property Designation(Lease Number): 8.Well Name and Number: FEE-PRIVATE,ADL 590(TPH)ADL384314(BHL) Falls Creek#6 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): '10.Field/Pool(s): N/A Ninilchik Field /Beluga&Tyonek Gas Pool 11.Present Well Condition Summary: �` � Total Depth measured 9,060 feet Plugs measured 6,000 fER E C E I\4 E fiwl true vertical 8,292 feet Junk measured N/A feet U L MC Effective Depth measured 8,959 feet Packer measured 4,046 feet true vertical 8,210 feet true vertical 3,815 feet AiG C Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 80' 80' Surface 3,521' 9-5/8" 3,521' 3,337' 5,750 psi 3,090 psi Intermediate Production 9,050' 5-1/2" 9,050' 8,284' 10,640 psi 7,480 psi Liner 01Wi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.4#/L-80 4,130'MD 3,892'ND Baker SABL-3 4,046'MD 3,815'ND Packers and SSSV(type,measured and true vertical depth) SLB tubing-ret ScSSSV 162'MD 162'ND 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 204 0 0 131 Subsequent to operation: 0 1040 0 0 168 14.Attachments(required per 20 AAC 25 070,25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations 1=1 Exploratory❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas Q WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-358 Contact Taylor Nasse Email tnasse(Whilcorp.com Printed Name Taylor Nasse Title Operations Engineer I Signature Phone 907-777-8354 Date ?, 3/ Asir RBDMSNM AUG - 2 2015 Form 10-404 Revised 5/2015 Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date FCU-06 50-133-20645-00-00 314-582 6/22/15 6/22/15 Daily Operations: 06/22/2015- Monday PTW and JSA. Spot equipment and rig up lubricator. Pressure test to 250 psi low and 3,500 psi high. Flow at 230K at 131 psi. RIH w/2-1/8" x 20' HC, 6 spf, 60 deg phase perf gun and tie into Halliburton CBL dated 11-Nov-14. Run correlation log#1 and send to town. Town had us shift 2' and perf from 5,400' to 5,420' (Blg 135) with well flowing. Fired gun with 132 psi on tubing. Psi went to 135 psi. Field is monitoring well in office. POOH. All shots fired. RIH w/2-1/8" x 20' HC, 6 spf, 60 deg phase perf gun and tie into Pollard correlation log#1 and send to town.Town had us shift 2' and perf from 5,058'to 5,078' (Blg 90) with well flowing. Fired gun with 132 psi on tubing. . Field is monitoring well in office. POOH.All shots fired. RIH w/,2- 1/8" x 10' HC, 6 spf, 60 deg phase perf gun and tie into Pollard correlation log#1 and send to town. Town had us shift 2' and perf from 5,048 to 5,058' (BIg90) with well flowing. Fired gun with 145 psi on tubing. Field is monitoring well in office. POOH. All shots fired. RIH w/2-1/8" x 20' HC, 6 spf, 60 deg phase perf gun and tie into Pollard correlation log#1 and send to town. Town had us shift 2' and perf from 4,470'to 4,490' (Blg 70) with well flowing. Fired gun with 165 psi on tubing. . Field is monitoring well in office. POOH. All shots fired. Rig down lubricator and turn well over to field. * Ninilchik Unit Well: Falls Creek#6 14 SCHEMATIC PTD: 214-137 API: 50-133-20645-00 Ililrorp Alaska,LLC RKB=18.60' CASING DETAIL 1 fo Size Type Wt Grade Conn. ID Top Btm 16" .. _ 16" Conductor 109 X-56 Weld 16" Surf 80' . !I IV1 9-5/8" Surf.Csg 40 L-80 BTC 8.835" Surf 3,521' 5-1/2" Prod Casing 17 P-110 CDC 4.892" Surf 9,050' ,4 TUBING 2-7/8" Production 6.4 L-80 EUE-8rd 2.441" Surf 4,130' gLLL JEWELRY DETAIL . ' ; " No. MD TVD Item X TOC @ 1 152' 152' CIM ++ 3,020' 2 162' 162' SLB TRMAXX 5E SCSSSV w/2.312"Bore ID 3 4,046' 3,815' Baker SABL-3 Packer 9-5/8"�+ 0 i +r 4 4,130' 3,892' Wireline re-entry guide. 5 6,000 5,600' Posi-Set Plug w/10 ft.cement IC 4$ w r ,ir PERFORATION DETAIL + Top Btm Top Btm Gun Y Sands Amt SPF Status Date 141.11 f ri (MD) (MD) (TVD) (TVD) Size 11 BIg 70 4,470' 4,490' 4,203' 4,222' 20' 2" 12 Open 06/22/15 Sir BIg 90 5,048' 5,078' 4,733' 4,761' 30' 2" 12 Open 06/22/15 BIg 135 5,400 5,420' 5,053' 5,071' 20' 2" 12 Open 06/22/15 .{ BIg140 5,524' 5,558' 5,166' 5,197' 24' 2" 6 Open 12/20/14 I` X T-1 5,586' 5,606' 5,223' 5,241' 20' 2" 6 Open 12/19/14 llt 5,589' 5,609' 5,225' 5,244' 20' 2" 6 Open 12/04/14 4,, Yew, 1-6 6,018' 6,031' 5,616' 5,628' 13' 2" 6 Isolated 12/04/14 Ilt 6,066' 6,084' 5,660' 5,676' 18' 2" 6 Isolated 12/04/14 8-1/2" , ' T-8 6,302' 6,322' 5,874' 5,892' 20' 2" 6 Isolated 12/04/14 Hole 3 7,300' 7,350' 6,782' 6,830' 50' 2" 6 Isolated 11/24/14 1-20 7,300' 7,350' 6,782' 6,830' 50' 2" j 66 Isolated 11/29/14 'Nr�; • 4 r'ri,dt iiiA F42 t"gin BIg70 a0 x.. w Wellhead connection 4.5"Otis *4 pe: BIg90 .4 K BIg135 1 e BI 140 7 .s+...•,t T-1 tt . r,, . e ii T-6 T8 k 1 sb ' •."+ •• 1-20 4111.:_„„aii,.._5.5" ' .r PBTD=8,959'MD/8,210'ND TD=9,060 MD/8,292'ND Updated by DMA 07-06-15 7-1//7;1„4' F i • �w\��1�j�sv THE STATE Alaska Oil and Gas ��, of Ti\ SIKj\ Conservation Commission -._ _: A 1 it#x 7.- 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 t� ,��1`� Main: 907.279.1433 OFALAS NNEU JUL 0 $ 1 Fax: 907.276.7542 Sip i• www.aogcc.alaska.gov Tyler Nasse ! 3 7 Operations Engineer p2 I Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Ninilchik Field, Beluga and Tyonek Gas Pool, Falls Creek#6 Sundry Number: 315-358 Dear Mr. Nasse: 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, Daniel T. Seamount, Jr. Commissioner DATEDthis Zda 2015 l y of June, Encl. ECE 1 VED STATE OF ALASKA 'UN 10 201:-) ALASKA OIL AND GAS CONSERVATION COMMISSION qr— &Ili-16 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown❑ Suspend p Perforate Q , Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other. ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Dell Number. Hilcorp Alaska,LLC Exploratory ❑ Development 2 - 214-137 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-133-20645-00 ' 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O.701 Will planned perforations require a spacing exception? Yes ❑ No ❑, Falls Creek#6 " 9.Property Designation(Lease Number): 10.Field/Pool(s): /2c= {r ilvv#KDL 590(TPH)ADL384314(BHL) Ninilchik Field /Beluga&Tyonek Gas Pool /S PRESENT WELL CONDITION SUMMARY 11. / > is 6 U, Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 9,060' ' 8,292' ' 8,959' 8,210' N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 80' 16' 80' 80' Surface 3,521' 9-5/8" 3,521' 3,337' 5,750psi 3,090psi Intermediate Production 9,050' 5-1/2" 9,050' 8,284' 10,640psi 7,480psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8" 6.4#/L-80 4,130' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Baker SABL-3/SLB tubing-retrievable ScSSSV 4,046'/162'MD and 3,815'/162'ND 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development Q Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 06/16/15 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS 0 . WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Taylor Nasse Email tnasse(a�hilcorp.com Printed Name Taylor Nasse Title Operations Engineer Signature --U /,�� Phone 777-8354 Date 6/g/iJ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 315- 355( Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No Subsequent Form Required: I C) 110 LI 'APPROVED BY Lf )211s Approved by: . COMMISSIONER THE COMMISSION Date: /1 n �..A.I ... _ '' /O /3 -- • - - Submit Form and Well Prognosis Well: Falls Creek#6 llilcorp Alaska,LL Date:06/09/2015 Well Name: Falls Creek#6 API Number: 50-133-20645-00 Current Status: Producing Leg: Estimated Start Date: June 16, 2014 Rig: Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-137 First Call Engineer: Taylor Nasse (907)777-8354 (0) (907) 903-0341 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824(C) AFE Number: Estimated Bottom Hole Pressure: —3,530 psi at 8,210' TVD (Assumed 0.43 psi/ft gradient) Max. Anticipated Surface Pressure: —2,710 psi (0.10 psi/ft gas gradient) Brief Well Summary Falls Creek#6 is a grass roots well that is currently producing from the Tyonek and Beluga sands. The well consists of 9-5/8" surface casing and 5-1/2" production casing with 2-7/8"tubing/packer completion. Objective of Work Add perforations in the Beluga sands. E-Line Procedure 1. MIRU e-line and pressure control equipment. PT lubricator to 250 psi low/3,500 psi high. 2. Perforate the Beluga sands with 2" 6 SPF 60 deg phased perf guns. All intervals are planned for 12 SPF so each will be shot twice. Depths are from the Halliburton reference GR/CCL/CBL dated 11 November, 2014. Send the correlation pass to Taylor Nasse and David Buthman for confirmation. Gross Proposed Perforated Intervals Sands Top (MD) Btm (MD) FT Beluga BIg70 ±4,472' ±4,492' ±20 Beluga BIg90 ±5,050' ±5,080' ±30 Beluga BIg135 ±5,402' ±5,422' ±20 3. POOH. 4. Flow well through test separator and record water and gas rates. 5. If any of the Beluga sands are not commercial,then the zone will be plugged back with a bridge plug. 6. RD e-line. 7. Turn well over to production. Attachments: Current and Proposed Wellbore Schematics Ninilchik Unit 14 Well: Falls Creek#6 SCHEMATIC PTD: 214-137 API: 50-133-20645-00 Hilmrp Alaska,Lit RKB=18.60' CASING DETAIL -4„. -!17 :, Size Type Wt Grade Conn. ID Top Btm 16"4id 16" Conductor 109 X-56 Weld 16" Surf 80' 9-5/8" Surf.Csg 40 L-80 BTC 8.835" Surf 3,521' , 5-1/2" Prod Casing 17 P-110 CDC 4.892" Surf 9,050' • -21 TUBING 2-7/8" Production 6.4 L-80 EUE-8rd 2.441" Surf 4,130' JEWELRY DETAIL No. MD ND Item I *. TOC @ 1 152' 152' CIM 3,020' 2 _ 162' 162' SLB TRMAXX 5E SCSSSV w/2.312"Bore g ,# 3 4,046' 3,815' Baker SABL-3 Packer 9-5/8"' ' a '* 4 4,130' 3,892' Wireline re-entry guide 5 6,000' 5,600' Posi-Set Plug w/10 ft.cement 1 . . :*. PERFORATION DETAIL Sands Top Btm Top Btm Amt Gun SPF Status Date ti (MD) (MD) (ND) (ND) Size • R BIg140 5,524' 5,558' 5,166' _ 5,197' 24' 2" 6 Open 12/20/14 • 5,586' 5,606' 5,223' 5,241' 20' 2" 6 Open 12/19/14 T-1 5,589' 5,609' 5,225' , 5,244' 20' 2" 6 Open 12/04/14 6,018' 6,031' 5,616' 5,628' 13' 2" 6 Isolated 12/04/14 T-6 6,066' 6,084' 5,660' 5,676' 18' 2" 6 Isolated 12/04/14 ,14).:#,,, T-8 _ 6,302' 6,322' 5,874' 5,892' 20' 2" 6 Isolated 12/04/14 7,300' 7,350' 6,782' _ 6,830' 50' 2" 6 Isolated 11/24/14 t T-20 7,300' 7,350' 6,782' 6,830' 50' 2" 6 Isolated 11/29/14 8-1/2" ,3 . Hole 4,.'. i .r 4 r.►t a 1/41 s ":, j BTI-g1 j. . Y, •Y A1v, - �, T-6 y, J T-8 Y tit • T-20 55" ,. *i i' PBTD=8,959'MD/8,210'ND TD=9,060 MD/8,292'ND Updated by DMA 01-15-15 Ninilchik Unit II Well: Falls Creek#6 • PROPOSED SCHEMATIC PTD: 214-137 API: 50-133-20645-00 Hilcorp Alaska,LLA. RKB=18.60' CASING DETAIL ��il Size Type Wt Grade Conn. ID Top Btm It' " th 16" Conductor 109 X-56 Weld 16" Surf 80' 9-5/8" Surf.Csg 40 L-80 BTC 8.835" Surf 3,521' ' 1 , 5-1/2" Prod Casing 17 P-110 CDC 4.892" Surf 9,050' r 2 ' TUBING l 2-7/8" Production 6.4 L-80 EUE-8rd 2.441" Surf 4,130' • JEWELRY DETAIL No. MD ND Item • ' TOC @ 1 152' 152' CIM 3,020' 2 162' 162' SLB TRMAXX 5E SCSSSV w/2.312"Bore 3 4,046' 3,815' Baker SABL-3 Packer 9-5/8" 4 4,130' 3,892' Wireline re-entry guide ' 5 6,000' 5,600' Posi-Set Plug w/10 ft.cement 0• 1 „ PERFORATION DETAIL Sands Top Btm Top Btm Amt Gun SPF Status Date (MD) (MD) (ND) (ND) Size Blg 70 ±4,472' ±4,492' ±4,205' ±4,224' _ 20' 2" 12 Proposed _ Blg 90 ±5,050' ±5,080' ±4,735' ±4,762' 30' 2" 12 Proposed Blg 135 ±5,402' ±5,422' ±5,055' ±5,073' 20' 2" 12 Proposed BIg140 5,524' 5,558' 5,166' 5,197' 24' _ 2" 6 Open 12/20/14 p T-1 5,586' 5,606' 5,223' 5,241' 20' 2" 6 Open 12/19/14 5,589' 5,609' 5,225' 5,244' 20' 2" 6 Open 12/04/14 1-6 6,018' 6,031' 5,616' 5,628' 13' 2" 6 Isolated 12/04/14 _ • ,, 6,066' 6,084' 5,660' 5,676' 18' 2" 6 _ Isolated 12/04/14 8-1/2" • B - I, T-8 6,302' 6,322' _ 5,874' 5,892' 20' 2" 6 Isolated 12/04/14 Hole 20 7,300' 7,350' 6,782' 6,830' 50' 2" 6 Isolated 11/24/14 T- 7,300' 7,350' 6,782' 6,830' 50' 2" 6 Isolated 11/29/14 4 ::‘,.. 1 B BI 90Ig70 - BIg135 BIg140 T1 T-6 T-8 r+ T-20 5.5" ; -L I)�L • { PBTD=8,959'MD/8,210'TVD TD=9,060 MD/8,292'TVD Updated by TWN 06-09-15 STATE OF ALASKA A, A OIL AND GAS CONSERVATION CC SSION GAS WELL OPEN FLOW POTENTIAL TEST REPORT la.Test: U Initial U Annual U Special 1 b.Type Test: U Stabilized U Non Stabilized U Multipoint ❑ Constant Time Isochronal 0 Other: See Remarks 2.Operator Name: 5.Date Completed: 11.Permit to Drill Number: Hilcorp Alaska, LLC 12/23/2014 214-137 3.Address: 6. Date TD Reached: 12.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 11/6/2014 50-133-20645-00 4a.Location of Well(Governmental Section): 7. KB Elevation above MSL(feet): 13.Well Name and Number: Surface: 1906'FSL,2730'FWL,Sec 6,TIN,R12W,SM,AK 266.90 Falls Creek#6 Top of Productive Horizon: 8.Plug Back Depth(MD+TVD): 14.Field/Pool(s): 1774'FNL, 1713'FWL,Sec 6,TIN,R12W,SM,AK 6,000'MD/5,600'ND Total Depth: 9.Total Depth(MD+ND): Ninilchik Field/Beluga&Tyonek Gas 308'FNL, 1013'FWL,Sec 6,TIN, R12W,SM,AK 9,060'MD/8,292'ND 4b.Location of Well(State Base Plane Coordinates NAD 27): 10.Land Use Permit: 15.Property Designation: Surface: x- 240096.85 y-2269464.23 Zone- 4 N/A ADL 590(TPH)ADL384314(BHL) TPI: x- 239355 y-2271074 Zone- 4 16.Type of Completion(Describe): Total Depth: x- 238681.98 y-2272554.16 Zone- 4 2-7/8"Tubing,Naturally Perforated 17.Casing Size Weight per foot,lb. I.D.in inches Set at ft. 19. Perforations: From To 5-1/2" 17 4.892 9050 5,524'-5,558' 18.Tubing Size Weight per foot,lb. I.D.in inches Set at ft. 5,586'-5,606' 2-7/8" 6.4 2.441 4130 5,589'-5,609' 20.Packer set at ft: 21.GOR cf/bbl: 22.API Liquid Hydrocardbons: 23.Specific Gravity Flowing Fluid(G): 4,046 N/A N/A 0.56 24a.Producing through: 24b.Reservoir Temp: 24c. Reservoir Pressure: 24d.Barometric Pressure(Pa): 2 Tubing El Casing 103 F° 410 psia @ Datum 4915 NDSS psia 25.Length of Flow Channel(L): Vertical Depth(H): Gg: %COP: %N2: %H2S: ' Prover: Meter Run: Taps: 0.56 0.203 0.449 0 26. FLOW DATA TUBING DATA CASING DATA Prover Choke Pressure Diff. Temp. Pressure Temp. Pressure Temp. Duration of Flow No. Line X Orifice psig Hw F° psig F° psig F° Hr. Size(in.) Size(in.) 1. X - RECEIVED ED 2. X QED '>, 1 ::"1. 3. X SCO • VIE :UN 0f 2015 4. X 5. X AOGCC Basic Coefficient Flow Temp. Super Comp. No. (24-Hour) h Pressure Gravity Factor Rate of Flow Pm Factor Fg Q1 Mcfd Fb or Fp Ft g Fpv 1 2. . 3. 4. 5. Temperature for Separator for Flowing No. PrT Tr z Gas Fluid Gg G 1 2. 3. Critical Pressure 4. Critical Temperature - 5. pp��■■.. ! ,AUG6 Form 10-421 Rev. 7/2009 0 R I G I NAL ON REVER6�i1DB�1Ni72 2616 Submit in Duplicate Pc Pc2 f Pf2 No. Pt Pt2 Pc2-Pt2 Pw Pw2 Pc2-Pw2 Ps Ps2 Pf2-Ps2 1. 2. 3. 4. 5. 25. AOF (Mcfd) 860 n Remarks: The FC#6 well is a low rate gas well that has water entry into the wellbore. The well was not multistepped due to the concern of losing the well completely but the inflow was modeled in Prosper using the Jones IPR model to determine AOF. Please see attached Prosper outputs for the AOF determination. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Reservoir Engineer Date 6/5/2015 DEFINITIONS OF SYMBOLS AOF Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producin face were reduced to zero psia Fb Basic orifice factor Mcfd/ hwPm Fp Basic critical flow prover or positive choke factor Mcfd/psia Fg Specific gravity factor, dimensionless Fpv Super compressibility factor= dimensionless Ft Flowing temperature factor, dimensionless G Specific gravity of flowing fluid (air=1.000), dimensionless Gg Specific gravity of separator gas (air=1.00), dimensionless GOR Gas-oil ratio, cu. ft. of gas (14.65 psia and 60 degrees F) per barrel oil (60 degrees F) hw Meter differential pressure, inches of water H Vertical depth corresponding to L, feet (TVD) L Length of flow channel, feet(MD) n Exponent(slope) of back-pressure equation, dimensionless Pa Field barometric pressure, psia Pc Shut-in wellhead pressure, psia Pf Shut-in pressure at vertical depth H, psia Pm Static pressure at point of gas measurement, psia Pr Reduced pressure, dimensionless Ps Flowing pressure at vertical depth H, psia Pt Flowing wellhead pressure, psia Pw Static column wellhead pressure corresponding to Pt, psia Q Rate of flow, Mcfd (14.65 psia and 60 degrees F) Tr Reduced temperature, dimensionless T Absolute temperature, degrees Rankin Z Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the Manual of Back- Pressure Testing of Gas Wells, Interstate Oil Compact Commission, Oklahoma City, Oklahoma. Form 10-421 Revised 7/2009 Side 2 • HAK - O:\Alaska\Fief linilchik\Falls Creek\Wells\FCU-06' ;per\Falls Creek #6.Out Page 1 . SYSTEM SENSITIVITY ANALYSIS - Input Data . Top Node Pressure : 0 (psig) Water Gas Ratio : 0 (STB/MMscf) Condensate Gas Ratio : 0 (STB/MMscf) Surface Equipment Correlation : Beggs and Brill Vertical Lift Correlation : Petroleum Experts 2 Solution Node : Bottom Node Rate Method : Automatic - Linear Left-Hand Intersection : DisAllow HAK - O:\Alaska\Fief iinilchik\Falls Creek\Wells\FCU-06` ;per\Falls Creek #6.Out Page 2 ########################################### # SYSTEM SENSITIVITY ANALYSIS - Results # ########################################### dP Gas Oil Water Liquid VLP IPR Total dP dP dP Completion Rate Rate Rate Rate Pressure Pressure Skin Perforation Damage Completion Skin (MMscf/day) (STB/day) (STB/day) (STB/day) (psig) (psig) (psi) (psi) (psi) (psi) 0.00086105 0 0 0 1.59 409.77 0 0 0 0 0 0.046098 0 0 0 2.29 399.05 0 0 0 0 0 0.091334 0 0 0 3.85 387.98 0 0 0 0 0 0.13657 0 0 0 6.00 376.57 0 0 0 0 0 0.18181 0 0 0 8.53 364.78 0 0 0 0 0 0.22704 0 0 0 11.33 352.57 0 0 0 0 0 0.27228 0 0 0 14.31 339.91 0 0 0 0 0 0.31752 0 0 0 17.42 326.73 0 0 0 0 0 0.36275 0 0 0 20.61 312.97 0 0 0 0 0 0.40799 0 0 0 23.87 298.56 0 0 0 0 0 0.45323 0 0 0 27.18 283.38 0 0 0 0 0 0.49846 0 0 0 30.52 267.31 0 0 0 0 0 0.5437 0 0 0 33.89 250.18 0 0 0 0 0 0.58894 0 0 0 37.28 231.76 0 0 0 0 0 0.63417 0 0 0 40.69 211.69 0 0 0 0 0 0.67941 0 0 0 44.12 189.47 0 0 0 0 0 0.72465 0 0 0 47.56 164.21 0 0 0 0 0 0.76988 0 0 0 51.01 134.22 0 0 0 0 0 0.81512 0 0 0 54.46 95.11 0 0 0 0 0 0.86036 0 0 0 57.92 7.60 0 0 0 0 0 First Total Maximum Maximum Maximum Gas Total WellHead WellHead Node dP dP NoSlip Erosional C Grain Rate Skin Pressure Temperature Temperature Friction Gravity Velocity Velocity Factor Diameter (MMscf/day) (psig) (deg F) (deg F) (psi) (psi) (ft/sec) (ft/sec) (inches) 0.00086105 0 0 46.02 46.02 0.0016161 1.59 0.30128 1919.256 0.062882 0.0001 0.046098 0 0 46.32 46.32 0.65919 1.63 15.963 1906.528 3.34904 0.013359 0.091334 0 0 46.62 46.62 2.13 1.72 31.582 1905.162 6.63077 0.044071 0.13657 0 0 46.92 46.92 4.13 1.86 47.107 1902.803 9.90263 0.079285 0.18181 0 0 47.22 47.22 6.50 2.02 62.493 1899.505 13.1598 0.11148 0.22704 0 0 47.52 47.52 9.11 2.20 77.697 1895.302 16.3979 0.13839 0.27228 0 0 47.83 47.83 11.88 2.39 92.679 1890.222 19.6123 0.16012 0.31752 0 0 48.13 48.13 14.76 2.60 107.399 1884.288 22.7989 0.17757 0.36275 0 0 48.43 48.43 17.71 2.81 121.821 1877.522 25.9535 0.19161 0.40799 0 0 48.73 48.73 20.72 3.03 135.908 1869.945 29.0722 0.20302 0.45323 0 0 49.03 49.03 23.76 3.26 149.670 1861.832 32.1555 0.21236 0.49846 0 0 49.33 49.33 26.84 3.49 162.954 1852.448 35.1867 0.22017 0.5437 0 0 49.62 49.62 29.93 3.72 175.852 1842.574 38.1753 0.2267 HAK - O:\Alaska\Fie linilchik\Falls Creek\Wells\FCU-06' ;per\Falls Creek #6.Out Page 3 0.58894 0 0 49.92 49.92 33.04 3.96 188.299 1831.980 41.1138 0.23225 0.63417 0 0 50.21 50.21 36.16 4.20 201.186 1824.844 44.0994 0.23695 0.67941 0 0 50.50 50.50 39.28 4.44 213.164 1814.771 46.9843 0.24104 0.72465 0 0 50.79 50.79 42.42 4.68 224.784 1804.471 49.8281 0.24458 0.76988 0 0 51.08 51.08 45.56 4.93 236.054 1794.005 52.6316 0.24763 0.81512 0 0 51.37 51.37 48.70 5.17 246.987 1783.432 55.3958 0.25038 0.86036 0 0 51.66 51.66 51.84 5.42 256.776 1769.981 58.0291 0.25282 Erosional Maximum Liquid Gas Velocity Turner Loading Rate Flag Velocity Flag (MMscf/day) (ft/sec) 0.00086105 No No 0.046098 No No 0.091334 No No 0.13657 No No 0.18181 No No 0.22704 No No 0.27228 No No 0.31752 No No 0.36275 No No 0.40799 No No 0.45323 No No 0.49846 No No 0.5437 No No 0.58894 No No 0.63417 No No 0.67941 No No 0.72465 No No 0.76988 No No 0.81512 No No 0.86036 No No . Solution Point . Gas Rate : 0.83533 (MMscf/day) Oil Rate : 0 (STB/day) Water Rate : 0 (STB/day) Liquid Rate : 0 (STB/day) Solution Node Pressure : 56.01 (psig) dP Friction : 50.10 (psi) dP Gravity : 5.28 (psi) dP Total Skin : 0 (psi) dP Perforation : 0 (psi) dP Damage : 0 (psi) dP Completion : 0 (psi) Completion Skin : 0 Total Skin : 0 1A/a11hanrl I ini iirl flancih, • d52 Ef1S2 /I1n/f+21 HAK - O:\Alaska\Fief linilchik\Falls Creek\Wells\FCU-06' ;per\Falls Creek #6.Out Page 4 Wellhead Gas Density : 0.043595 (Ib/ft3) Wellhead Liquid Viscosity : 1.4117 (centipoise) Wellhead Gas Viscosity : 0.010935 (centipoise) Wellhead Superficial Liquid Velocity : 0 (ft/sec) Wellhead Superficial Gas Velocity : 292.065 (ft/sec) Wellhead Z Factor : 0.99775 Wellhead Interfacial Tension : 15.1034 (dyne/cm) Wellhead Pressure : 0 (psig) Wellhead Temperature : 51.50 (deg F) First Node Liquid Density : 48.508 (Ib/ft3) First Node Gas Density : 0.043595 (Ib/ft3) First Node Liquid Viscosity : 1.4117 (centipoise) First Node Gas Viscosity : 0.010935 (centipoise) First Node Superficial Liquid Velocity : 0 (ft/sec) First Node Superficial Gas Velocity : 292.065 (ft/sec) First Node Z Factor : 0.99775 First Node Interfacial Tension : 15.1034 (dyne/cm) First Node Pressure : 0 (psig) First Node Temperature : 51.50 (deg F) +++++++++++++++++++ + End of Report + +++++++++++++++++++ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: January 9, 2015 P. I. Supervisor FROM: Lou Grimaldi SUBJECT: SVS Inspection Petroleum Inspector Ninilchik Unit Paxton 8 (PTD 2141070) Falls Creek 6 (PTD 2141370) Hilcorp 1/7/2015: Traveled to Ninilchik Unit Paxton pad for SVS test of Paxton #8 and met with Hilcorp representative Charles Gomes (Pad operator). Paxton #8 passed the SVS test but the well cellar was completely frozen in - photo attached. Told Mr. Gomes to get cellar thawed out to where they could get at the annulus valves. Next I traveled to Falls Creek pad to perform an unannounced SVS test on Falls Creek#6. This was requested by AOGCC Inspection Supervisor Jim Regg since witness was waived for the initial SVS test (performed 12/10/14) due to lack of an available Inspector. Falls Creek#6 passed the SVS test. Based on observations at both locations, it appears that Hilcorp has no plans for placing wellhouses over wells they have added on these pads, deviating from the practice employed by initial operator Marathon. Unannounced visits during cold weather would be appropriate to confirm there are no freezing problems with the SVS. Summary: Paxton #8 and Falls Creek#6 passed AOGCC witnessed SVS tests performed on 1/7/15. Paxton #8 has a frozen well cellar; instructions were left with Hilcorp to thaw the cellar. Attachments: Photo (Paxton #8 frozen well cellar) 12115 — t -tku,tspr,,. - r j cc-402,- u N F r� c tLQ> - sea t•eel 2015-0109_Location LtiPaxton-8_Fa11sCk-6—g1 .docx P_age 1 of 2 • Paxton #8 (PTD 2141070) Photo by AOGCC Inspector L. Grimaldi 1/7/2015 T Well houses over wells that — '7r were drilled prior to 1 Hilcorp taking over Paxton . - pad operations F ` l` ' - N " ,. s 1C '-� -pis .�- r L E ri 0 Paxton#8 frozen well cellar;annulus valves are below ice Y _ A -a 2015-0109—Location_Paxton-8_FallsCk-6—g 1 .docx Page 2 of 2 • Regg, James B (DOA) From: Noble, Robert C (DOA) Reeic, ll'(J/5 Sent: Wednesday, January 21, 2015 11:42 AM To: Regg, James B (DOA) Subject: Paxton #8 (M 2A10-70) Paxton #8 water was gone except for it being wet in the bottom. I could not take a picture as they were bleeding gas for E-line work. Bob Noble AOGCC 333 W. 7th Ave. Ste. 100 Anch AK. 99501 Cell 907-299-1362 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 Bob Noble at 907-299-1362 or bob.noble@alaska.gov • Pb 2-141370 Regg, James B (DOA) From: Paul Chan <pchan@hilcorp.com> Sent: Monday, November 10, 2014 3:59 PM �1 i1Il Zll4 To: Regg, James B (DOA);Wallace, Chris D (DOA) 111 Cc: Luke Keller Subject: RE: Falls Creek#6 (PTD 214-137) Jim Luke and I appreciated the time to clarify that pressure control for e-line operations on the Falls Creek#6 well is not needed as the wellbore is hydraulically isolated from the formation as the well is cased/cemented and the casing has been pressure tested to 3500 psi. If you require any further information, please do not hesitate to contact either one of us. Thanks Paul Chan E� VI Senior Operations Engineer N� Kenai Asset Hilcorp Alaska LLC (907) 777—8333 (w) (907)444—2881 (c) (907) 345—3161 (h) From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Monday, November 10, 2014 12:41 PM To: Paul Chan; Wallace, Chris D (DOA) Subject: RE: Falls Creek #6 (PTD 214-137) So you would close the bind rams if use of secondary well control equipment were required ? How will the well control standing order be adjusted? Jim Regg Supervisor, Inspections AOGCC 907-793-1236 Sent from Samsung Mobile Original message From: Paul Chan <pchan@hilcorp.com> Date: 11/10/2014 1 1:04 AM (GMT-09:00) To: "Wallace, Chris D (DOA)" <chris.wallace@alaska.gov>,"Regg, James B (DOA)" <jim.regg@alaska.gov> Subject: Falls Creek#6 (PTD 214-137) i Jim/Chris Reference: Approved Sundry 314-582 (attached) Hilcorp Alaska respectfully requests a variance to 20 AAC 25.037 (Well control requirements for other drilling and completion operations)to not pressure test the wireline well control equipment while running the e-line logs as stated in the Well Prognosis calling for a pressure test in Step 8 b. Hilcorp AK proposes to meet the requirements of 20 AAC.25.037 as follows: The BOPE equipment rigged up and tested for the drilling of the well is in place; The well is cased and cemented. The casing has passed a 3500 psi pressure test for 30 minutes; The wellbore will be swapped over to 8.6 ppg kill weight fluid Best regards Paul Chan Senior Operations Engineer Kenai Asset Hilcorp Alaska LLC (907) 777—8333 (w) (907)444—2881 (c) (907) 345—3161 (h) 2 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. J - _13 7 Well History File Identifier Organizing (done) Two-sided ❑ Rescan Needed RESCAN: OVERSIZED: NOTES: Co Items: ❑ Maps: Grayscale Items: tp4.13f ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: Maria Date: /O ,S /s/ ifil P Project Proofing BY: MD Date: b /3— Is! 4 Scanning Preparation x 30 = 1 ZSO + =TOTAL PAGES ON 03 (Count does not include cover sheet) BY: deb Date: a /� /� /s/ Production Scanning CC�� Stage 1 Page Count from Scanned File: n( b if(count-(Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ✓YES NO BY: 411:110 Date: al Jo I 'Jr-' /s/ V /) p Stage 1 If NO in stage 1, page(s)discrepancies were found: YES NO y� BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: 6° ----'\(\ie), Digital version appended by: Meredith Michal M1 Date: � 1 /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: 0-.5 1-4- Scanning Scanning is complete at this point unless rescanning is required. 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N 0 w Ce 0- re UJ 0 U J Q Z 'ICC w A CO 7 o es 0_ cn _ � o 0 N a E 1.0 U N U o J co < Y Co V a r H J H_ a O LL N 2 i N W ZD CV = N, J 0 Q Z c Z Nilk Q o z E CI E v Co z m • N 0) N CO I o� m M F .a T m N m m cc rn w U « 'Q O E0 E ¢ a 2 0 l Dinger Hilcorp Alaska, L. ��j 3 q Drilling Tech 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 ifk„rp Tele: 907 777-8389 E-mail: cdinger@hilcorp.com DATE: 1/23/2015 To: Alaska Oil & Gas Conservation Commission Meredith Guhl Petroleum Geology Assitant 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL Falls Creek #6 CD : Definitive Survey Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittVE, I7 777.8580 Received By: Date: JAN 2 3 2015 Angela K. Singh AOGCC RECEIVA Hilcorp Alaska, LLC Post Office Box 244027 JAN 2 0 2015 Anchorage,AK 99524-4027 3800 Centerpoint Drive AOGCC CC Suite 1400 Anchorage,AK 99503 Phone: 907/777.8300 January 19, 2015 Fax: 907/777.8301 Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, Alaska 99501 Re: Falls Creek#6 Form 10-407 PTD: 214-137 API: 50-133-20645-00-00 Dear Commissioner: Please find the enclosed Well Completion Form 10-407 for Falls Creek #6. Please do not hesitate to contact me should you have any questions or need additional information. Sincerely, HILCORP ALASKA, L C Cody Dinger Drilling Technician (907)777-8389 cdinger@hilcorp.com 1 of 1 1 r -RECEIVED :IAN 2 0 2015 STATE OF ALASKA __ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la Well Status: Oil❑ Gas ❑, • SPLUG❑ Other ❑ Abandoned ❑ Suspended❑ lb.Well Class: 20AAC 25105 20AAC 25 110 Development ❑J • Exploratory❑ GINJ❑ WINJ❑ WAG❑ WDSPL 0 No.of Completions: Service ❑ Stratigraphic Test❑ 2 Operator Name: 5.Date Comp,Susp.,or 12.Permit to Drill Nu r. Hilcorp Alaska,LLC Abend.. .12/21/2014 :5'/y_4z 2141377 3,/if-6 y 3 P '- 17 3 Address 6.Date Spudded. 13.API Number. // 3800 Centrpoint Drive,Suite 1400 Anchorage,AK 99503 •10/19/2014 50-133.20845-00-00' 4a Location of Well(Governmental Section). 7.Date TD Reached: 14 Well Name and Number Surface 1906'FSL,2730'FWL,Sec 6,T1N,R12W,SM,AK • • 11/6/2014 Fells Creek#6 d Top of Productive Horizon. 8.KB(ft above MSL): 266.9 • 15.Field/Pool(s): 1774'FNL,1713'FWL,Sec 8,T1N,R12W,SM,AK GL(ft above MSL). 248.3 . Ninilchik Total Depth: 9.Plug Back Depth(MD+TVD): Belugs/Tyonek Gas Pool• 308'FNL,1013'FWL,Sec 6,TIN,R12W,SM,AK • 8959 MD/8210'TVD - CO 701 - 4b Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: / Surface x- 240096.85 • y- 2269464.23 • Zone- 4 • 9060'MD!8292'TVD . ADL 590(TPH)ADL384314(BHL)'(c cj rrjV'�r TPI x- 239355 y- 2271074 Zone- 4 11.SSSV Depth(MD+TVD). 17.Land Use Permit 417> Total Depth: x- 238681.98 y- 2272554.16 Zone- 4 1e2'MD/162'TVD N/A ` i.z:.t.4.- 18 Directional Survey: Yes . ❑' No 0 19.Water Depth,ifOffshore' 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). 22Re-dnllLaterat Top Window MD/TVD ROP-DGR-EWR 2"15"MD,DGR-EW R 2"l5"TVD,FL 275"MD/TVD,GRL 2"MD/TVD,LWD CL 2"MD/TVD,DDL 2"MDiTVD N/A 23 CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 16" 109 X-56 • Surface ea Surface e0' Driven N/A 9-5/8" 40 L-80 Surface 3520' Surface 3337' 12-1/4" 270 bbl 124,46.6 bbl 15.2# - 5-1/2" 17 P-110 Surface 9050' Surface 8283' 8-1/2' 175 bbl 13.54,147 bbl 15.74 24 Open to production or injection? Yes 2 No ❑ 25. TUBING RECORD If Yes,list each interval open(MD+TVD of Top and Bottom,Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 2.7/8" 4,130' 4,04E MD/3,815'TVD 5524-5560 MD(5166-5197)with 12 shots per foot,5589-5609 MD(5225-5244) with 12 shots per foot 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. L.TOM ;Was hydraulic fracturing used during completion? Yes 0 No❑, • 1 '7. DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED }f _ 27 PRODUCTION TEST Date First Production. Method of Operation(Flowing,gas lift,etc) 12/23/2014 Flowina • Date of Test Hours Tested Production for Oil-Bbl Gas-MCF: Water-Bbl. Choke Size. Gas-Oil Ratio 1/2/2015 24 Test Period ....0.-0 626.9 0 NA Flow Tubing Casing Press' Calculated 'Oil-Bbl Gas-MCF Water-Bbl Oil Gravity-API(corr). Press. 201 0 24-Hour Rate 0 626 9 - 0 28 CORE DATA Conventional Core(s)Acquired? Yes 0 No❑Q • Sidewall Cores Acquired? Yes❑ No❑, • If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed) Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25 071 /, 6 .IS ....40,(,//4//:(f------ err) 1. ?'}.,y, Form 10-407 Revised 10/2012 CONTINUED ON REVERSE Submit original only RBDMS JAN 1 2 2015 G 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? [ Yes ❑ No If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if needed, and submit detailed test information per 20 AAC 25.071. Beluga 2596 2497 Beluga 50 3599 3408 Beluga 90 4644 4363 Tyonek 5581 5218 Tyonek10 6728 6261 Tyonek 65 8480 7826 Tyonek 83 8836 8110 Formation at total depth: 31. List of Attachments:Well Schematic,Days vs.Depth Graph,MW vs. Depth Graph,Definitive Directional Survey, Daily Drilling and Completion Composite Reports,Casing and Cement Reports. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Luke Keller Email: Ikeller@hilcorp.com Printed Name: L e Keller Title: Drilling Engineer Signature: Phone: 907-777-8395 Date: / / ` ` /S- INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1b: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25 071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 Ninilchik Unit • Well: Falls Creek#6 SCHEMATIC PTD: 214-137 API: 50-133-20645-00 llilnorp Alaska,IIA. RKB=18.60' CASING DETAIL 1 Os, Size Type Wt Grade Conn. ID Top Btm IG I 16" Conductor 109 X-56 Weld 16" Surf 80' 1 9-5/8" Surf.Csg 40 L-80 BTC 8.835" Surf 3,521' + I 5-1/2" Prod Casing 17 P-110 CDC 4.892" Surf 9,050' 64 TUBING 2-7/8" Production 6.4 L-80 EUE-8rd 2.441" Surf 4,130' IP JEWELRY DETAIL No. MD ND Item "s „ 0 TOC@ 1 152' 152' CIM 3020' 2 162' 162' SLB TRMAXX 5E SCSSSV w/2.312"Bore .4, ",�,d , 13 4,046' 3,815' Baker SABL-3 Packer tillt ,s"` 4 4,130' 3,892' Wireline re-entry guide 5 6,000' 5,600' Posi-Set Plug w/10 ft.cement '° t v0 'c i .` PERFORATION DETAIL Sands Top Btm Top Btm Amt Gun SPF Status Date (MD) (MD) (ND) (ND) Size BIg140 5,524' 5,558' 5,166' 5,197' 24' 2" 6 Open 12/20/14 5,586' 5,606' 5,223' 5,241' 20' 2" 6 Open 12/19/14 ! T-1 5,589' 5,609' ' 5,225' 5,244' 20' 2" 6 Open 12/04/14 6,018' 6,031' 5,616' 5,628' 13' 2" 6 Isolated 12/04/14 T-6 6,066 6,084' 5,660' 5,676' 18' 2" 6 Isolated 12/04/14 T-8 6,302' 6,322' 5,874' 5,892' 20' 2" 6 Isolated 12/04/14 40 ON iltrt4; 7,300' 7,350' 6,782' 6,830' 50' 22,;,; " 6 Isolated 11/24/14 T-20 7,300' 7,350' 6,782' 6,830' 50' 2" 6 Isolated 11/29/14 8-1/2" Li .., vi,„ Hole a BIg140 T-1 �. T-6 is T-8 T-20 • • 5.5" �'4, ,*k.1:177,44,1 PBTD=8,959'MD/8,210'TVD TD=9,060 MD/8,292'TVD Updated by DMA 01-15-15 _ ox_ I I� a acme F„ v'nNo3E°, m cc 3 `0° m O1 x v., :_.> in- m E a o m ° o t0 m- o ° o + 0' z- 2• mm- .2mc au o ,n° c '" Em o 0 c 0. m - a E �° m a a E g c rn ro m p_,20 -. o .-7, 2 .U 'c an d. ow . .. . n .n o F U 2 , 0 ¢c o mina o A or; . 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Hilcorp Energy Company Ninilchik Unit Falls Creek Falls Creek 6 501332064500 501332064500 Sperry Drilling Definitive Survey Report 04 December, 2014 ...Am .A111111111111111L . .. . . .41•1111111111111L ..41111111k . . ,4 HALLIBURTON Sperry Drilling - , ' Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Falls Creek#6 ' Project: Ninilchik Unit TVD Reference: Falls Creek New As-built @ 266.80usft , Site: Falls Creek MD Reference: Falls Creek New As-built @ 266.80usft Well: Falls Creek#6 North Reference: True Wellbore: Falls Creek 6 Survey Calculation Method: Minimum Curvature Design: Falls Creek 6 Database: Sperry EDM-NORTH US+CANADA Project Ninilchik Unit 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 Using geodetic scale factor • Well Falls Creek#6 Well Position +NI-S 0.00 usft Northing: 2,269,464.23 usft ' Latitude: 60.20445247°N +E/-W 0.00 usft Easting: 240,096.85 usft . Longitude: -151.42867427 Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: • 248.30 usft Wellbore Falls Creek 6 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2014 10/5/2014 16.67 73.21 55,237 Design Falls Creek 6 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 18.50 Vertical Section: Depth From(ND) +N/-S +E/-W Direction (usft) (usft) (usft) (") 18.50 0.00 0.00 335.25 Survey Program Date 12/4/2014 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 128.78 3,491.57 Falls Creek 6 MWD(Falls Creek 6) MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 10/19/2014 3,552.59 9,025.92 Falls Creek 6 MWD(Falls Creek 6) MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 10/19/2014 Survey Map Map Vertical MD Inc Azi ND TVDSS +NI-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 18.50 0.00 0.00 18.50 -248.30 0.00 0.00 2,269,464.23 240,096.85 0.00 0.00 UNDEFINED 128.78 1.51 36.52 128.77 -138.03 1.17 0.86 2,269,465.38 240,097.74 1.37 0.70 MWD+SC+sag(1) 189.23 1.65 29.20 189.19 -77.61 2.57 1.76 2,269,466.76 240,098.67 0.41 1.59 MWD+SC+sag(1) 253.40 1.46 44.72 253.34 -13.46 3.95 2.79 2,269,468.12 240,099.72 0.72 2.42 MWD+SC+sag(1) 313.57 2.35 31.11 313.48 46.68 5.56 3.97 2,269,469.70 240,100.94 1.65 3.39 MWD+SC+sag(1) 376.51 3.10 20.46 376.35 109.55 8.26 5.23 2,269,472.37 240,102.25 1.43 5.31 MWD+SC+sag(1) 438.81 3.07 10.99 438.56 171.76 11.47 6.13 2,269,475.57 240,103.23 0.82 7.85 MWD+SC+sag(1) 501.96 3.47 356.77 501.60 234.80 15.04 6.35 2,269,479.13 240,103.52 1.43 11.00 MWD+SC+sag(1) 561.24 3.81 342.07 560.77 293.97 18.70 5.64 2,269,482.81 240,102.90 1.67 14.62 MWD+SC+sag(1) 621.43 4.21 333.69 620.81 354.01 22.59 4.05 2,269,486.72 240,101.38 1.18 18.82 MWD+SC+sag(1) 681.18 4.49 337.64 680.39 413.59 26.72 2.19 2,269,490.89 240,099.61 0.69 23.35 MWD+SC+sag(1) 742.13 5.30 328.58 741.12 474.32 31.33 -0.19 2,269,495.55 240,097.34 1.83 28.53 MWD+SC+sag(1) 804.91 5.51 329.93 803.62 536.82 36.41 -3.21 2,269,500.70 240,094.43 0.39 34.41 MWD+SC+sag(1) 12/4/2014 1:25:41PM Page 2 COMPASS 5000.1 Build 70 Halliburton ' Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Falls Creek#6 Project: Ninilchik Unit TVD Reference: Falls Creek New As-built @ 266.80usft Site: Falls Creek MD Reference: Falls Creek New As-built @ 266.80usft Well: Falls Creek#6 North Reference: True Wellbore: Falls Creek 6 Survey Calculation Method: Minimum Curvature Design: Falls Creek 6 Database: Sperry EDM-NORTH US+CANADA 1Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 868.42 5.70 326.41 866.82 600.02 41.67 -6.48 2,269,506.03 240,091.27 0.62 40.56 MWD+SC+sag(1) 931.67 5.79 322.95 929.75 662.95 46.84 -10.14 2,269,511.27 240,087.72 0.57 46.78 MWD+SC+sag(1) 992.82 6.35 332.99 990.56 723.76 52.31 -13.54 2,269,516.82 240,084.45 1.96 53.17 MWD+SC+sag(1) 1,056.79 7.22 326.46 1,054.09 787.29 58.81 -17.37 2,269,523.40 240,080.76 1.82 60.68 MWD+SC+sag(1) 1,119.41 7.82 325.20 1,116.17 849.37 65.59 -21.97 2,269,530.28 240,076.30 0.99 68.77 MWD+SC+sag(1) 1,182.58 8.69 325.65 1,178.68 911.88 73.06 -27.12 2,269,537.86 240,071.32 1.38 77.70 MWD+SC+sag(1) 1,245.71 9.30 327.68 1,241.04 974.24 81.31 -32.54 2,269,546.22 240,066.08 1.09 87.46 MWD+SC+sag(1) 1,308.46 10.00 326.63 1,302.90 1,036.10 90.14 -38.24 2,269,555.18 240,060.57 1.15 97.87 MWD+SC+sag(1) 1,371.30 11.62 326.00 1,364.62 1,097.82 99.95 -44.78 2,269,565.12 240,054.24 2.58 109.52 MWD+SC+sag(1) 1,434.07 13.98 326.30 1,425.83 1,159.03 111.50 -52.53 2,269,576.84 240,046.75 3.76 123.25 MWD+SC+sag(1) 1,497.57 15.63 326.78 1,487.22 1,220.42 125.04 -61.47 2,269,590.56 240,038.10 2.61 139.29 MWD+SC+sag(1) 1,561.80 17.27 328.41 1,548.81 1,282.01 140.40 -71.21 2,269,606.13 240,028.70 2.65 157.31 MWD+SC+sag(1) 1,624.66 19.39 329.83 1,608.48 1,341.68 157.37 -81.34 2,269,623.32 240,018.94 3.45 176.97 MWD+SC+sag(1) 1,688.01 21.24 330.54 1,667.89 1,401.09 176.45 -92.27 2,269,642.63 240,008.42 2.95 198.87 MWD+SC+sag(1) 1,751.16 23.20 332.99 1,726.35 1,459.55 197.50 -103.54 2,269,663.92 239,997.61 3.43 222.71 MWD+SC+sag(1) 1,814.38 24.42 334.58 1,784.19 1,517.39 220.40 -114.81 2,269,687.05 239,986.84 2.18 248.22 MWD+SC+sag(1) 1,877.45 23.87 335.07 1,841.74 1,574.94 243.74 -125.78 2,269,710.63 239,976.37 0.93 274.02 MWD+SC+sag(1) 1,941.03 24.82 334.47 1,899.66 1,632.86 267.45 -136.96 2,269,734.58 239,965.71 1.54 300.22 MWD+SC+sag(1) 2,001.11 25.83 334.48 1,953.97 1,687.17 290.64 -148.03 2,269,758.00 239,955.14 1.68 325.92 MWD+SC+sag(1) 2,067.27 24.96 335.02 2,013.74 1,746.94 316.30 -160.14 2,269,783.92 239,943.60 1.36 354.29 MWD+SC+sag(1) 2,130.56 25.29 334.75 2,071.04 1,804.24 340.63 -171.54 2,269,808.49 239,932.72 0.55 381.16 MWD+SC+sag(1) 2,194.18 24.09 334.67 2,128.84 1,862.04 364.66 -182.90 2,269,832.76 239,921.89 1.89 407.74 MWD+SC+sag(1) 2,257.43 24.53 335.31 2,186.48 1,919.68 388.26 -193.90 2,269,856.58 239,911.40 0.81 433.77 MWD+SC+sag(1) 2,320.32 23.65 332.74 2,243.90 1,977.10 411.33 -205.13 2,269,879.90 239,900.67 2.18 459.43 MWD+SC+sag(1) 2,383.77 23.83 332.66 2,301.98 2,035.18 434.03 -216.85 2,269,902.84 239,889.45 0.29 484.95 MWD+SC+sag(1) 2,444.33 22.79 333.96 2,357.59 2,090.79 455.44 -227.62 2,269,924.48 239,879.15 1.92 508.90 MWD+SC+sag(1) 2,507.57 23.05 333.11 2,415.84 2,149.04 477.49 -238.59 2,269,946.76 239,868.65 0.67 533.52 MWD+SC+sag(1) 2,571.20 23.93 333.68 2,474.20 2,207.40 500.16 -249.95 2,269,969.67 239,857.79 1.43 558.86 MWD+SC+sag(1) 2,634.72 23.55 333.64 2,532.34 2,265.54 523.08 -261.30 2,269,992.83 239,846.94 0.60 584.43 MWD+SC+sag(1) 2,698.10 23.75 333.66 2,590.40 2,323.60 545.86 -272.58 2,270,015.85 239,836.15 0.32 609.84 MWD+SC+sag(1) 2,760.28 25.24 334.39 2,646.98 2,380.18 569.04 -283.87 2,270,039.27 239,825.37 2.45 635.62 MWD+SC+sag(1) 2,823.91 24.23 334.03 2,704.77 2,437.97 593.01 -295.45 2,270,063.49 239,814.31 1.60 662.23 MWD+SC+sag(1) 2,886.82 24.05 334.39 2,762.18 2,495.38 616.18 -306.64 2,270,086.89 239,803.62 0.37 687.96 MWD+SC+sag(1) 2,950.14 24.26 334.02 2,819.96 2,553.16 639.51 -317.92 2,270,110.45 239,792.85 0.41 713.87 MWD+SC+sag(1) 3,015.02 23.47 333.32 2,879.29 2,612.49 663.04 -329.56 2,270,134.23 239,781.72 1.29 740.10 MWD+SC+sag(1) 3,077.97 24.49 333.47 2,936.81 2,670.01 685.91 -341.02 2,270,157.34 239,770.76 1.62 765.67 MWD+SC+sag(1) 3,141.51 25.97 332.36 2,994.28 2,727.48 710.02 -353.35 2,270,181.71 239,758.95 2.45 792.73 MWD+SC+sag(1) 3,204.71 25.35 334.38 3,051.25 2,784.45 734.48 -365.62 2,270,206.43 239,747.21 1.70 820.08 MWD+SC+sag(1) 3,268.23 24.12 334.61 3,108.94 2,842.14 758.46 -377.07 2,270,230.66 239,736.29 1.94 846.66 MWD+SC+sag(1) 3,331.49 24.36 334.12 3,166.62 2,899.82 781.88 -388.30 2,270,254.31 239,725.56 0.50 872.63 MWD+SC+sag(1) 12/4/2014 1:25:41 PM Page 3 COMPASS 5000.1 Build 70 Halliburton • Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Falls Creek#6 Project: Ninilchik Unit TVD Reference: Falls Creek New As-built @ 266.80usft Site: Falls Creek MD Reference: Falls Creek New As-built @ 266.80usft Well: Falls Creek#6 North Reference: True Wellbore: Falls Creek 6 Survey Calculation Method: Minimum Curvature Design: Falls Creek 6 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 3,391.46 25.86 334.19 3,220.93 2,954.13 804.78 -399.40 2,270,277.45 239,714.97 2.50 898.07 MWD+SC+sag(1) 3,455.81 25.73 333.69 3,278.86 3,012.06 829.94 -411.70 2,270,302.86 239,703.21 0.39 926.06 MWD+SC+sag(1) 3,491.57 25.69 332.81 3,311.08 3,044.28 843.79 -418.68 2,270,316.86 239,696.53 1.07 941.57 MWD+SC+sag(1) 3,552.59 25.95 333.69 3,366.01 3,099.21 867.52 -430.64 2,270,340.85 239,685.09 0.76 968.13 MWD+SC+sag(2) 3,616.88 24.83 333.93 3,424.09 3,157.29 892.26 -442.81 2,270,365.84 239,673.46 1.75 995.68 MWD+SC+sag(2) 3,680.56 24.79 333.22 3,481.89 3,215.09 916.19 -454.70 2,270,390.02 239,662.09 0.47 1,022.39 MWD+SC+sag(2) 3,744.17 24.75 332.30 3,539.65 3,272.85 939.88 -466.90 2,270,413.97 239,650.41 0.61 1,049.02 MWD+SC+sag(2) 3,802.87 24.74 331.56 3,592.96 3,326.16 961.56 -478.46 2,270,435.90 239,639.32 0.53 1,073.55 MWD+SC+sag(2) 3,867.17 24.35 333.75 3,651.45 3,384.65 985.28 -490.73 2,270,459.88 239,627.56 1.54 1,100.23 MWD+SC+sag(2) 3,931.21 23.88 336.20 3,709.91 3,443.11 1,008.98 -501.80 2,270,483.81 239,617.01 1.73 1,126.39 MWD+SC+sag(2) 3,995.35 23.91 336.04 3,768.55 3,501.75 1,032.74 -512.32 2,270,507.79 239,807.01 0.11 1,152.36 MWD+SC+sag(2) 4,058.86 24.02 335.45 3,826.58 3,559.78 1,056.26 -522.92 2,270,531.53 239,596.92 0.42 1,178.16 MWD+SC+sag(2) 4,120.70 23.92 334.85 3,883.09 3,616.29 1,079.06 -533.47 2,270,554.55 239,586.86 0.43 1,203.28 MWD+SC+sag(2) 4,185.13 23.79 334.07 3,942.02 3,675.22 1,102.57 -544.71 2,270,578.30 239,576.14 0.53 1,229.34 MWD+SC+sag(2) 4,246.14 23.76 333.56 3,997.85 3,731.05 1,124.64 -555.56 2,270,600.60 239,565.77 0.34 1,253.92 MWD+SC+sag(2) 4,308.84 23.50 336.04 4,055.29 3,788.49 1,147.37 -566.26 2,270,623.56 239,555.56 1.64 1,279.05 MWD+SC+sag(2) 4,371.09 23.35 335.66 4,112.41 3,845.61 1,169.95 -576.39 2,270,646.35 239,545.93 0.34 1,303.79 MWD+SC+sag(2) 4,433.95 22.92 334.75 4,170.22 3,903.42 1,192.37 -586.74 2,270,668.99 239,536.06 0.89 1,328.49 MWD+SC+sag(2) 4,497.39 23.66 335.16 4,228.49 3,961.69 1,215.10 -597.36 2,270,691.94 239,525.94 1.19 1,353.57 MWD+SC+sag(2) 4,560.96 23.32 334.79 4,286.79 4,019.99 1,238.06 -608.08 2,270,715.13 239,515.72 0.58 1,378.91 MWD+SC+sag(2) 4,623.89 22.97 334.13 4,344.65 4,077.85 1,260.38 -618.74 2,270,737.67 239,505.54 0.69 1,403.64 MWD+SC+sag(2) 4,687.81 23.92 334.21 4,403.30 4,136.50 1,283.27 -629.82 2,270,760.80 239,494.96 1.49 1,429.07 MWD+SC+sag(2) 4,750.43 24.06 333.45 4,460.51 4,193.71 1,306.12 -641.05 2,270,783.88 239,484.23 0.54 1,454.52 MWD+SC+sag(2) 4,812.89 23.75 332.58 4,517.61 4,250.81 1,328.67 -652.53 2,270,806.68 239,473.23 0.75 1,479.81 MWD+SC+sag(2) 4,876.75 23.54 334.79 4,576.11 4,309.31 1,351.62 -663.89 2,270,829.87 239,462.38 1.43 1,505.41 MWD+SC+sag(2) 4,938.56 23.12 333.80 4,632.87 4,366.07 1,373.68 -674.50 2,270,852.15 239,452.25 0.93 1,529.89 MWD+SC+sag(2) 5,001.17 23.30 335.43 4,690.41 4,423.61 1,395.97 -685.08 2,270,874.67 239,442.15 1.07 1,554.56 MWD+SC+sag(2) 5,064.78 24.18 335.84 4,748.64 4,481.84 1,419.30 -695.64 2,270,898.22 239,432.10 1.41 1,580.16 MWD+SC+sag(2) 5,127.77 25.21 335.72 4,805.86 4,539.06 1,443.30 -706.44 2,270,922.44 239,421.82 1.64 1,606.48 MWD+SC+sag(2) 5,191.28 25.05 335.38 4,863.36 4,596.56 1,467.85 -717.60 2,270,947.23 239,411.20 0.34 1,633.45 MWD+SC+sag(2) 5,253.16 24.41 334.47 4,919.57 4,652.77 1,491.30 -728.57 2,270,970.91 239,400.74 1.20 1,659.34 MWD+SC+sag(2) 5,316.43 25.29 334.64 4,976.98 4,710.18 1,515.31 -739.99 2,270,995.16 239,389.84 1.40 1,685.92 MWD+SC+sag(2) 5,379.39 24.64 333.97 5,034.06 4,767.26 1,539.25 -751.51 2,271,019.35 239,378.84 1.13 1,712.49 MWD+SC+sag(2) 5,441.51 24.24 333.11 5,090.61 4,823.81 1,562.26 -762.96 2,271,042.60 239,367.89 0.86 1,738.18 MWD+SC+sag(2) 5,505.17 23.53 332.59 5,148.82 4,882.02 1,585.20 -774.72 2,271,065.79 239,356.63 1.16 1,763.93 MWD+SC+sag(2) 5,569.00 24.21 333.85 5,207.19 4,940.39 1,608.26 -786.36 2,271,089.09 239,345.50 1.33 1,789.75 MWD+SC+sag(2) 5,632.10 24.87 334.73 5,264.59 4,997.79 1,631.87 -797.72 2,271,112.94 239,334.64 1.20 1,815.95 MWD+SC+sag(2) 5,694.29 24.76 334.80 5,321.04 5,054.24 1,655.48 -808.85 2,271,136.79 239,324.03 0.18 1,842.05 MWD+SC+sag(2) 5,758.62 24.29 334.76 5,379.56 5,112.76 1,679.64 -820.23 2,271,161.19 239,313.18 0.73 1,868.75 MWD+SC+sag(2) 5,822.27 23.44 334.06 5,437.77 5,170.97 1,702.87 -831.35 2,271,184.65 239,302.56 1.41 1,894.50 MWD+SC+sag(2) 12/4/2014 1:25:41PM Page 4 COMPASS 5000.1 Build 70 A Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Falls Creek#6 Project: Ninilchik Unit TVD Reference: Falls Creek New As-built @ 266.80usft Site: Falls Creek MD Reference: Falls Creek New As-built @ 266.80usft Well: Falls Creek#6 North Reference: True Wellbore: Falls Creek 6 Survey Calculation Method: Minimum Curvature Design: Falls Creek 6 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 5,883.93 24.67 333.82 5,494.07 5,227.27 1,725.44 -842.39 2,271,207.46 239,292.01 2.00 1,919.62 MWD+SC+sag(2) 5,948.18 24.44 333.34 5,552.51 5,285.71 1,749.35 -854.27 2,271,231.62 239,280.65 0.47 1,946.31 MWD+SC+sag(2) 6,011.03 23.73 332.37 5,609.89 5,343.09 1,772.18 -865.97 2,271,254.69 239,269.45 1.29 1,971.94 MWD+SC+sag(2) 6,073.03 25.12 332.89 5,666.34 5,399.54 1,794.95 -877.75 2,271,277.71 239,258.16 2.27 1,997.55 MWD+SC+sag(2) 6,135.19 24.74 332.65 5,722.71 5,455.91 1,818.24 -889.74 2,271,301.26 239,246.68 0.63 2,023.72 MWD+SC+sag(2) 6,199.21 25.40 333.17 5,780.70 5,513.90 1,842.40 -902.09 2,271,325.67 239,234.86 1.09 2,050.83 MWD+SC+sag(2) 6,262.86 24.49 332.39 5,838.41 5,571.61 1,866.27 -914.37 2,271,349.80 239,223.10 1.52 2,077.65 MWD+SC+sag(2) 6,327.52 25.70 333.89 5,896.97 5,630.17 1,890.73 -926.75 2,271,374.53 239,211.25 2.11 2,105.05 MWD+SC+sag(2) 6,390.43 24.90 333.79 5,953.84 5,687.04 1,914.86 -938.60 2,271,398.91 239,199.92 1.27 2,131.93 MWD+SC+sag(2) 6,454.02 24.43 332.85 6,011.63 5,744.83 1,938.58 -950.52 2,271,422.88 239,188.53 0.96 2,158.45 MWD+SC+sag(2) 6,516.02 24.84 333.32 6,067.99 5,801.19 1,961.62 -962.21 2,271,446.17 239,177.33 0.73 2,184.27 MWD+SC+sag(2) 6,579.68 24.44 333.47 6,125.85 5,859.05 1,985.35 -974.10 2,271,470.15 239,165.96 0.64 2,210.80 MWD+SC+sag(2) 6,642.78 23.68 332.74 6,183.47 5,916.67 2,008.29 -985.73 2,271,493.34 239,154.83 1.29 2,236.51 MWD+SC+sag(2) 6,706.22 24.18 336.53 6,241.46 5,974.66 2,031.54 -996.75 2,271,516.81 239,144.32 2.55 2,262.23 MWD+SC+sag(2) 6,768.86 23.65 336.83 6,298.72 6,031.92 2,054.86 -1,006.80 2,271,540.34 239,134.77 0.87 2,287.61 MWD+SC+sag(2) 6,832.07 24.47 336.03 6,356.44 6,089.64 2,078.48 -1,017.10 2,271,564.18 239,124.98 1.40 2,313.37 MWD+SC+sag(2) 6,895.40 23.95 335.82 6,414.20 6,147.40 2,102.19 -1,027.70 2,271,588.11 239,114.90 0.83 2,339.34 MWD+SC+sag(2) 6,957.43 25.42 336.13 6,470.56 6,203.76 2,125.85 -1,038.24 2,271,612.00 239,104.87 2.38 2,365.25 MWD+SC+sag(2) 7,021.02 25.09 335.15 6,528.07 6,261.27 2,150.56 -1,049.43 2,271,636.95 239,094.22 0.84 2,392.37 MWD+SC+sag(2) 7,082.89 24.44 335.02 6,584.25 6,317.45 2,174.07 -1,060.35 2,271,660.68 239,083.82 1.05 2,418.29 MWD+SC+sag(2) 7,147.72 23.48 334.40 6,643.49 6,376.69 2,197.87 -1,071.59 2,271,684.73 239,073.09 1.53 2,444.62 MWD+SC+sag(2) 7,210.75 24.23 334.88 6,701.14 6,434.34 2,220.91 -1,082.51 2,271,707.99 239,062.67 1.23 2,470.11 MWD+SC+sag(2) 7,273.02 24.97 335.23 6,757.76 6,490.96 2,244.41 -1,093.44 2,271,731.72 239,052.25 1.21 2,496.03 MWD+SC+sag(2) 7,337.01 25.97 335.38 6,815.53 6,548.73 2,269.41 -1,104.94 2,271,756.97 239,041.30 1.57 2,523.55 MWD+SC+sag(2) 7,399.74 25.45 334.79 6,872.04 6,605.24 2,294.09 -1,116.40 2,271,781.89 239,030.38 0.92 2,550.76 MWD+SC+sag(2) 7,462.18 24.82 334.03 6,928.57 6,661.77 2,318.01 -1,127.85 2,271,806.05 239,019.44 1.13 2,577.28 MWD+SC+sag(2) 7,526.58 24.28 333.50 6,987.15 6,720.35 2,342.02 -1,139.68 2,271,830.30 239,008.14 0.91 2,604.02 MWD+SC+sag(2) 7,589.92 24.65 331.27 7,044.80 6,778.00 2,365.25 -1,151.84 2,271,853.80 238,996.49 1.57 2,630.22 MWD+SC+sag(2) 7,653.01 24.25 330.96 7,102.24 6,835.44 2,388.12 -1,164.45 2,271,876.93 238,984.37 0.67 2,656.26 MWD+SC+sag(2) 7,716.46 24.31 332.79 7,160.08 6,893.28 2,411.12 -1,176.75 2,271,900.20 238,972.57 1.19 2,682.31 MWD+SC+sag(2) 7,779.05 23.34 332.69 7,217.33 6,950.53 2,433.60 -1,188.33 2,271,922.92 238,961.48 1.55 2,707.56 MWD+SC+sag(2) 7,842.82 24.36 333.05 7,275.65 7,008.85 2,456.55 -1,200.09 2,271,946.11 238,950.23 1.62 2,733.33 MWD+SC+sag(2) 7,905.68 25.84 333.78 7,332.58 7,065.78 2,480.39 -1,212.02 2,271,970.21 238,938.82 2.41 2,759.98 MWD+SC+sag(2) 7,968.19 26.84 333.35 7,388.60 7,121.80 2,505.23 -1,224.37 2,271,995.31 238,927.01 1.63 2,787.70 MWD+SC+sag(2) 8,030.18 28.20 333.54 7,443.57 7,176.77 2,530.85 -1,237.17 2,272,021.20 238,914.76 2.20 2,816.33 MWD+SC+sag(2) 8,092.54 29.14 333.64 7,498.28 7,231.48 2,557.65 -1,250.48 2,272,048.28 238,902.04 1.51 2,846.23 MWD+SC+sag(2) 8,157.12 29.51 333.64 7,554.59 7,287.79 2,585.99 -1,264.52 2,272,076.91 238,888.61 0.57 2,877.85 MWD+SC+sag(2) 8,219.14 30.74 333.54 7,608.23 7,341.43 2,613.86 -1,278.36 2,272,105.08 238,875.37 1.98 2,908.96 MWD+SC+sag(2) 8,284.14 31.96 334.03 7,663.74 7,396.94 2,644.20 -1,293.30 2,272,135.74 238,861.10 1.92 2,942.77 MWD+SC+sag(2) 8,346.66 32.91 334.05 7,716.51 7,449.71 2,674.35 -1,307.98 2,272,166.20 238,847.08 1.52 2,976.29 MWD+SC+sag(2) 12/4/2014 1:25:41 PM Page 5 COMPASS 5000.1 Build 70 Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Falls Creek#6 Project: Ninilchik Unit TVD Reference: Falls Creek New As-built @ 266.80usft Site: Falls Creek MD Reference: Falls Creek New As-built @ 266.80usft Well: Falls Creek#6 North Reference: True Wellbore: Falls Creek 6 Survey Calculation Method: Minimum Curvature Design: Falls Creek 6 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,408.98 34.05 334.80 7,768.49 7,501.69 2,705.36 -1,322.82 2,272,197.52 238,832.91 1.95 3,010.67 MWD+SC+sag(2) 8,470.42 35.74 336.16 7,818.88 7,552.08 2,737.34 -1,337.39 2,272,229.81 238,819.03 3.03 3,045.81 MWD+SC+sag(2) 8,534.65 37.11 336.71 7,870.56 7,603.76 2,772.30 -1,352.64 2,272,265.08 238,804.55 2.19 3,083.94 MWD+SC+sag(2) 8,598.58 38.22 337.27 7,921.17 7,654.37 2,808.25 -1,367.90 2,272,301.36 238,790.06 1.82 3,122.98 MWD+SC+sag(2) 8661.89 37.55 336.75 7,971.13 7,704.33 2,844.04 -1,383.09 2,272,337.47 238,775.66 1.17 3,161.84 MWD+SC+sag(2) 8,724.87 37.23 336.05 8,021.17 7,754.37 2,879.09 -1,398.40 2,272,372.84 238,761.11 0.84 3,200.08 MWD+SC+sag(2) 8,787.63 36.68 335.95 8,071.32 7,804.52 2,913.56 -1,413.74 2,272,407.63 238,746.51 0.88 3,237.80 MWD+SC+sag(2) 8,850.41 36.28 335.82 8,121.80 7,855.00 2,947.63 -1,428.99 2,272,442.02 238,732.01 0.65 3,275.13 MWD+SC+sag(2) 8,914.68 35.96 334.92 8,173.72 7,906.92 2,982.06 -1,444.78 2,272,476.79 238,716.97 0.96 3,313.01 MWD+SC+sag(2) 8,976.64 35.86 334.61 8,223.90 7,957.10 3,014.94 -1,460.27 2,272,509.99 238,702.19 0.33 3,349.35 MWD+SC+sag(2) 9,025.92 35.55 333.99 8,263.92 7,997.12 3,040.85 -1,472.75 2,272,536.17 238,690.28 0.97 3,378.11 MWD+SC+sag(2) , 9,060.00 35.55 333.99 8,291.65 . 8,024.85 3,058.66 -1,481.44 2,272,554.16 238,681.98 0.00 3,397.92 PROJECTED to TD Checked By: Patrick Walker- Approved By: Cary Taylor Date: 12/4/2014 1:25:41PM Page 6 COMPASS 5000.1 Build 70 v , - act: NII111Chik Unit WELL DETAILS: Falls 5 NAD 1927(NADCON CONUS) Alaska Zone 04 • - HALLIBURTON Site: Falls Creek Ground Level: 248.30 Well: Falls Creek#6 +N/-S +E/-W Northing Fasting Latittude Longitude Slot Sperry Drilling Services Wellbore: Falls Creek 6 0.00 0.00 2269464.23 240096.85 60.20445247°N -151.42867427 Plan: Falls Creek 6 REFERENCE INFORMATION Co-ordinate(N/E)Reference:Well Falls Creek#6,True North Vertical(TVD)Reference:Falls Creek New As-built Ia 266.80usft Measured Depth Reference: Falls Creek New As-built 266.80usft -833— Calculation Method:Minimum Curvature -417- 0- 417- 500 833— = \ 1000 1250- - 1500 1667- 1-000 2083— _ '20 2500- 3000 2917— 3500 C 3333— _ 9 5/8' d) - O 3750— p000 U) _ N_ _ *".4167- 4583 167-4583500 U - j5000— 500 a) - 2 5417- H _ 6000 58337 6500 6250— _ 1000 6667- 1500 7083— = 6000 7500— _ $600 7917— 9000 �Q60 8333— Gteev- e4" 8750— Gte6 �a\\e • 9167- 9583— 11111111111111 I I 1111111 II 'Iiii 1111111111it 11111111111111 III II 11111111 1111111111 I ltll lllllllllllllll 11111111111 -2500 -2083 -1667 -1250 -833 -417 0 417 833 1250 1667 2083 2500 2917 3333 3750 4167 4583 5000 5417 5833 6250 Vertical Section at 335.25° (1250 usft/in) 'HA• LLN3URTON Project: Ninilchik Unit WELL DETAILS: Falls Creek#6 Sperry Drilling ServicesSite: Falls Creek Ground Level: 248.30 Well: Falls Creek#6 +N/-S +E/-W Northing Easting Latittude Longitude Slot Wellbore: Falls Creek 6 0.00 0.00 2269464.23 240096.85 60.20445247°N -151.42867427 Plan: Falls Creek 6 REFERENCE INFORMATION Co-ordinate(N/E)Reference:Well Falls Creek#6,True North Vertical(TVD)Reference:Falls Creek New As-built l 266.80usft _ Measured Depth Reference: Falls Creek New As-built(a 266.80usft Calculation Method:Minimum Curvature 3750— 3500- - bhp(0 3250_ vQ"SGtyek 6y91 3000— 0\sCc 4000 2750— -1150 "15* 2500— -y50 2250— 650 C — 6250 2000- 3 550 n _ 1750— 5500 c — 5X50 1500— 5000 0 a5* 1250— py50 tpCA 1000— 350 _ 3500 3250 750— 9 5/8" pp g0 2150 500— 2500 — 2250 se 250— ,�50 1250 0— 500 M Azimuths to True North • Magnetic North:16.67° -250— Magnetic Field _ Strength:55237.0snT Dip Angle:73.21* Date:10/5/2014 Model:BGGM2014 -500— I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I -2500 -2250 -2000 -1750 -1500 -1250 -1000 -750 -500 -250 0 250 500 750 1000 West(-)/East(+)(500 usft/in) )(i�, , FC #6 MW Vs Depth 0 500 Falls Creek#6 1000 1500 2000 2500 3000 3500 4000 .L 4500 a ar v 5000 v 5500 2 6000 6500 7000 7500 8000 8500 9000 9500 10000 --- ---- 8 9 10 11 12 13 14 Mud Density(ppg) • • 4 s FC #6 Days Vs Depth 0 Falls Creek#6 1000 2000 3000 4000 Y I- a+ a 5000 6000 7000 8000 9000 10000 0 5 10 15 20 25 30 Days 4 • f I • • v Hilcorp Energy Company CASING&CEMENTING REPORT Lease&Well No Falls Creek Date 24-Oct-14 County Ninilchik State Alaska Supv Shane Barber/Doug Yessak CASING RECORD TD 3530 00 Shoe Depth 3519 94 PBTD 3434 51 Casing(Or Liner)Detail Setting Depths No of Jts Size Wt Grade THD Make Length Bottom Top SHOE 9 5/8" 40 BTC 1 Weatherford 1.89 3,519.94 3,518.05 2 9 5/8" 40 L-80 BTC US STEEL 82.08 3,518.05 3,435.97 Float collar 9 5/8" 40 BTC Weatherford 1.46 3,435.97 3,434.51 82 9 5/8" 40 L-80 BTC US STEEL 3,409.61 3,434.51 24.90 Pup 9 5/8" 40 L-80 BTC US STEEL 2.00 24.90 22.90 Hgr _ 0.60 22.90 22.30 RKB 22.30 22 30 0.00 Totals Csg Wt On Hook 92,000 Type Float Collar Weatherford No Hrs to Run 10 5 Csg Wt On Slips 64,000 Type of Shoe Weatherford Casing Crew Weatherford Fluid Descnption Kla Shield 9 1 Liner hanger Info(Make/Model) Liner top Packer? _Yes X No Liner hanger test pressure Centralizer Placement 41 bow spnngs AT 80' No centralizers last 300' CEMENTING REPORT Preflush(Spacer) Type SEAL BOND Density(ppg) 10 5 Volume pumped(BBLs) 30 Lead Slurry Type TYPE 1 Density(ppg) 12 Volume pumped(BBLs) 270 Mixing/Pumping Rate(bpm) 4 5 Tail Slurry Type TYPE 1 Density(ppg) 15 2 Volume pumped(BBLs) 46 6 - Mixing/Pumping Rate(bpm) 4 5 y Post Flush(Spacer) y Type_ FW Density(ppg) 8 3 Rate(bpm) 4 5 Volume 10 re E Displacement: Type KlaShiel Density(ppg) 9 1 Rate(bpm) 4 Volume(actual/calculated) 263.6/260 FCP(psi) 820 Pump used for disp MP#2/Rig Plug Bumped? Yes x No Bump press 0 Casing Rotated? Yes X No Reciprocated? Yes x No %Returns dunng job 100 Cement returns to surface? X Yes No Spacer returns? X Yes No Vol to Surf 30 SPACER,118 CEMENT Cement In Place At 2 40 Date 10/24/2014 Estimated TOC SURFACE Method Used To Determine TOC VISUAL/Wt Preflush(Spacer) Type Density(ppg) Volume pumped(BBLs) Lead Slurry Type Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm) Tall Slurry w Type Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm) y Post Flush(Spacer) 0 0 z Type Density(ppg) Rate(bpm) Volume NDisplacement: Type Density(ppg) Rate(bpm) Volume(actual/calculated) FCP(psi) Pump used for disp Plug Bumped? Yes No Bump press Casing Rotated? Yes No Reciprocated? Yes_No %Returns during lob Cement returns to surface? Yes_No Spacer returns?_Yes_No Vol to Surf Cement In Place At Date Estimated TOC Method Used To Determine TOC Post Job Calculations: Calculated Cmt Vol @ 0%excess 219 3 Total Volume cmt Pumped 270(lead)+46 6(tail)=316 6 bbls Cmt returned to surface 118 Calculated cement left in wellbore 316 6-219 3=198 6 bbls OH volume Calculated 191 9 OH volume actual 171 2 Actual V.Washout 0 ii -M • Hilcorp Energy Company CASING&CEMENTING REPORT Lease&Well No Falls Creek#6 Date 9-Nov-14 County KPB State Alaska Supv James Lott/Shane Barber CASING RECORD TD 9060 00 Shoe Depth 9049 75 PBTD 8959 24 Casing(Or Liner)Detail _ Setting Depths No of Jts Size Wt Grade THD Make _ Length Bottom Top _ SHOE 51/2" _ 17 CDC Weatherford 1.51 9,049.75 9,048.24 _ 2 5 1/2" 17 P-110 CDC US STEEL 86.74 9,048.24 8,961.50 Float collar 5 1/2" 17 CDC Weatherford 2.26 8,961.50 8,959.24 41 51/2" 17 P-110 CDC US STEEL 1,845.18 _ 8,959.24 7,114.06 RA pup 51/2" 17 P-110 CDC US STEEL 9.90 7,114.06 7,104 16 46 5 1/2" _ 17 P-110 CDC US STEEL 2,065.49 7,104.16 5,038.67 RA pup 5 1/2" 17 P-110 CDC US STEEL 9.60 5,038.67 5,029.07 112 5 1/2" 17 P-110 CDC US STEEL 5,007.60 5,029.07 21.47 Hgr 5 1/2" 17 P-110 CDC US STEEL 2.97 21.47 18.50 RKB 5 1/2" 17 P-110 CDC US STEEL 18.50 18.50 0.00 Csg Wt On Hook 110,000 Type Float Collar Weatherford No Hrs to Run 12 Csg Wt On Slips 80,000 Type of Shoe Weatherford Casing Crew Weatherford Fluid Description 6%KCL Liner hanger Info(Make/Model) _ Liner top Packers _Yes X No Liner hanger test pressure Centralizer Placement 84 @ 45,18 @ 90' CEMENTING REPORT Preflush(Spacer) Type SEAL BOND Density(ppg) 12 Volume pumped(BBLs) 40 Lead Slurry Type Class G Density(ppg) 13 5 Volume pumped(BBLs) 175 Mixing/Pumping Rate(bpm) 3 7 Tall Slurry Type Class G Density(ppg) 15 7 _ Volume pumped(BBLs) 147 Mixing/Pumping Rate(bpm) 1 8 m Post Flush(Spacer) y Type Density(ppg) Rate(bpm) Volume LL Displacement: Type 6%KCL Density(ppg) 8 6 Rate(bpm) 5 Volume(actual/calculated) 210/208 t FCP(psi) 1890 Pump used for disp MP#1/Rig Plug Bumped? X Yes No Bump press 2200 _ Q Casing Rotated? Yes X No Reciprocated? _Yes x No %Retums dunng lob 96 271)Cement retums to surface Yes x No Spacer returns? Yes x No Vol to Surf 0 7 Cement In Place At 21.56 Date 11/9/2014 Estimated TOC 1,900 l�C./ Method Used To Determine TOC Losses and kit pressure Preflush(Spacer) Type Density(ppg) Volume pumped(BBLs) Lead Slurry Type Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm) Tail Slurry w Type Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm) r N Post Flush(Spacer) 0 o Type Density(ppg) Rate(bpm) Volume EJ Displacement: Type Density(ppg) Rate(bpm) Volume(actual/calculated) FCP(psi) Pump used for disp Plug Bumped' Yes No Bump press Casing Rotated? Yes _No Reciprocated? Yes No %Returns dunng lob Cement returns to surface's Yes_No Spacer returns?_Yes _No Vol to Surf Cement In Place At Date Estimated TOC Method Used To Determine TOC Post Job Calculations: Calculated Cmt Vol @ 0%excess 250 Total Volume cmt Pumped 175(lead)+147(tail)=322 bbls Cmt retumed to surface 0 Calculated cement left in wellbore 322 OH volume Calculated 226 OH volume actual 226 Actual%Washout 7 214137 teeth Nolan Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive 2 5 2 8 0 Anchorage, AK 99503 Tele: 907 777-8308 Hilrnrp %blau,1.1A, Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATE 01/14/15 DATA LOGGED t /20/2015 K BENDER To: Alaska Oil & Gas Conservation Commission Makana Bender RECEIVED Natural Resource Technician II 333 W 7th Ave Ste 100 JAN 1 6 2015 Anchorage, AK 99501 AOGCC DATA TRANSMITTAL Falls Creek 06 Mudlog Data Prints: 5" Formation Log MD 5" Formation Log TVD 2" Formation Log MD 2" Formation Log TVD 2" LWD Combo Log MD 2" LWD Combo Log TVD 2"Gas Ratio Log MD 2"Gas Ratio Log TVD 2" Drilling Dynamics MD 2" Drilling Dynamics TVD CD 1: digital version Mudlog Data Files Currently on the Disc (7) j. Daily Reports 112:201511:16 AM File folder I, DML Data 1/2/2015 11:16 AM File folder j„ Final Well Report 1'21201511:16 AM File folder j,. LAS Data 1.'21'201511:16 AM File folder j„ Log PDFs 121201511:16AM File folder 1. Log Tiffs 1;'21201511:16AM File folder ,l„ Show Reports 1'21201511:16 AM File folder Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received 8y OeatDate: 4 4,0`.\x11/77 'I'11E STATE Alaska Oil and Gas �w -�„ o f Conservation Commission ALASKA owl - 333 West Seventh Avenue i '3r �1---w- ; Anchorage,Alaska 99501 3572 (3c1\'ERNOR FILL �tiALKI-R Main:907.279.1433 OA. � Fax:907.276.7542 www.aogcc.alaska.gov Taylor Nasse Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Ninilchik Field, Beluga and Tyonek Gas Pool, Falls Creek#6 Sundry Number: 314-660 Dear Mr. Nasse: 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, Pavid J.' ayberry / Y Y Commissioner DATED this t\ltkday of December, 2014. Encl. RECEIVED w STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION orT3 ''Z-I" 1 9-- 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 ❑ Suspend❑ Plug Perforations ❑ Perforate 0 • Pull Tubing 0 Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate❑ Alter Casing❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development 0 . 214-137 • 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-133-20645-00-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O.701 Will planned perforations require a spacing exception? Yes ❑ No ❑✓ Falls Creek f16 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 590(TPH)ADL384314(BHL) ' Ninilchik Field /Beluga&Tyonek Gas Pool • 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): 9,060' 8,292' 8,959' 8,210' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16' 80' 80' Surface 3,521' 9-5/8" 3,521' 3,337' 5,750psi 3,090psi Intermediate Production 9,031' 5-1/2" 9,050' 8,284' 10,640psi 7,480psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8" 6.4#/L-80 4,130' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Baker SABL-3/SLB tubing-retrievable ScSSSV 4,046'/162'MD and 3,815'/162'ND 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑ . BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development Q •Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 12/15/2014 Commencing Operations: Oil ❑ Gas ❑� - WDSPL ❑ Suspended El 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned El Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Taylor Nasse Email tnasse@hilcorp.com Printed Name T or asse Title Operations Engineer Signature U Phone 777-8354 Date f V / / r COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes El No [ Subsequent Form Required: /0 —`/C 4 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date:)X'(% h ti ) 1� )c'/ A GtioNvA tr.12 pp Suborn Duplicate and Form 10-403(Revised 1 1.12) A months from the date of appr I. Attachments in Form ABE MS DEC 12 z; y A' 1z•/U''4` 14 , . , Well Prognosis Well: Falls Creek#6 Hilcorp Alaska,LL Date: 12/9/2014 Well Name: Falls Creek#6 API Number: 50-133-20643-00 Current Status: Producing Leg: Estimated Start Date: December 15, 2014 Rig: Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-137 First Call Engineer: Taylor Nasse (907)777-8354(0) (907)903-0341 (C) Second Call Engineer: Paul Chan (907)777-8333 (0) (907)444-2881 (C) AFE Number: 1413027C Estimated Bottom Hole Pressure: —3,770 psi at 8,690' ND (Assumed 0.43 psi/ft gradient) Max. Anticipated Surface Pressure: —2,893 psi (0.10 psi/ft gas gradient) Brief Well Summary Falls Creek#6 is a grass roots well that is currently completed but S perforated. The well consists of 9-5/8" surface casing and 5-1/2" production casing with 2-7/8"tubing/packer completion. Objective of Work Add perforations in the Beluga sands. ' E-Line Procedure 1. MIRU e-line and pressure control equipment. PT lubricator to 250 psi low/3,500 psi high. Note that the well is pressurized with nitrogen. 2. If necessary, bleed nitrogen pressure down as requested by the RE to establish a drawdown on the formation. 3. Perforate the Beluga sands with 2"6 SPF 60 deg phased perf guns.All intervals are planned for 12 SPF so each will be shot twice. Depths are from the Halliburton reference GR/CCL/CBL dated 11 November, 2014. Send the correlation pass to Taylor Nasse and David Buthman for confirmation. Gross Proposed Perforated Intervals Sands Top (MD) Btm (MD) FT Beluga BIg60 ±4,200' ±4,274' ±74 Beluga BIg70 ±4,476' ±4,488' ±12 Beluga BIg80 ±4,770' ±4,780' ±10 Beluga BIg90 ±5,050' ±5,080' ±30 Beluga BIg135 ±5,402' ±5,424' ±22 Beluga BIg140 ±5,526' ±5,560' ±34 • Well Prognosis Well: Falls Creek#6 Hilcorp Alaska,LL Date:12/9/2014 4. POOH. 5. Flow well through test separator and record water and gas rates. 6. If any of the Beluga sands are not commercial,then the zone will be plugged back with a bridge plug. 7. RD e-line. 8. Turn well over to production. Attachment: Proposed Wellbore Schematic Ninilchik Unit II Well: Falls Creek#6 PROPOSED COMPLETION PTD: 214-137 API: 50-133-20645-00 Hilcorp Alaska,LLC CASING DETAIL 16"49 1' Size I Type Wt Grade Conn. ID Top Btm i 16" 9-5/8" Conductor Surf.Csg 109 40 X-56 L-80 BTC Weld 16" Surf 8.835" Surf 80' • . 3,521' � 5-1/2" Prod Casing 17 P-110 CDC 4.892" Surf 9,050' TUBING 2-7/8" Production 6.4 L-80 EUE-8rd 2.441" Surf 4,130' ' TOC @ JEWELRY DETAIL - 3,020' No. MD TVD Item ' 1 152' 152' CIM 9-5/8":., k 2 162' 162' SLB TRMAXX SE SCSSSV w/2.312"Bore 3 4,046' 3,815' Baker SABL-3 Packer ' 4 4,130' 3,892' Wireline re-entry guide I PROPOSED PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) Ft Date Status BIg60 ±4,200' ±4,274' ±3,956' ±4,023' ±74 Future Proposed • • 1 BIg70 ±4,476' ±4,488' ±4,209' ±4,220' ±12 Future Proposed • BIg80 ±4,770' ±4,780' ±4,478' ±4,488' ±10 Future Proposed BIg90 ±5,050' ±5,080' ±4,735' ±4762' ±30 Future Proposed • ' BIg135 ±5,402' ±5,424' ±5,055' ±5,075' ±22 Future Proposed BIg140 ±5,526' ±5,560' ±5,168' ±5,199' ±34 Future Proposed 5,589' 5,609' 5,226' 5,242' 20 12/5/14 Open • ±5,659' ±5,705 ±5,289' ±5,331' ±46 Future Approved 8-1/2" IR • ±5,739' ±5,798' ±5,362' ±5,416' ±59 Future Approved , .3 Hole .1,•• ±5,843' ±5,851' ±5,457' ±5,464' ±8 Future Approved T 2 ±5,917' ±5,943' ±5,524' ±5,548' ±26 Future Approved ?4 • 6,018' 6,031' 5,617' 5,628' 13 12/5/14 Open BIg60 T-6 6,066' 6,084' 5,660' 5,674' 18 12/5/14 Open ' i 14 BIg70 T-8 6,302' 6,322' 5,874' 5,892' 20 12/5/14 Open be. 'li .T ±6,722' ±6,739' ±6,256' ±6,271' ±17 Future Approved s� rawn T-12 R Ws, BIg80 ±6,812' ±6,824' ±6,338' ±6,349' ±12 Future Approved r T-20 7,300' 7,350' 6,785' 6,827' 50 11/24/14 Open 1- •s BIg90 • 1 "• a.9. 1 -f : d BIg135 • - .,• ., BIg140 T-1 - _ T-2 m.r .a T-6 T-8 i T-12 o T-20 5.5,. ' t iv I A, PBTD=8,959'MD/8,210'ND TD=9,060 MD/8,292'ND Updated by TWN 12/09/14 °` F Alaska Oil and Gas 4,4 Conservation Commission cLASIA. 333 West Seventh Avenue tom?' Anchorage,Alaska 99501-3572 "rjr1s ' ';tv .ter Main:907.279.1433 Op •wLA•+Kr Fax:907.276.7542 www.aogcc.alaska.gov Taylor Nasse Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: Ninilchik Field, Beluga and Tyonek Gas Pools, Falls Creek#6 Sundry Number: 314-654 Dear Mr.Nasse: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P oerster Chair DATED this 8 day of December, 2014. Encl. • m p.---S (2S fort STATE OF ALASKA 1D F C 0 4 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION - p � APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1.Type of Request: Abandon 0 Plug for Redrill ❑ Perforate New Pool❑ Repair Well❑ Change Approved Program 0 Suspend 0 Plug Perforations ❑ Perforate 0 • Pull Tubing❑ Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate❑ Alter Casing❑ Other: 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development 0 • 214-137 • 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-133-20645-00-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O.701 • Will planned perforations require a spacing exception? Yes ❑ No ❑✓ _ Falls Creek#6 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 590(TPH)ADL384314(BHL) Ninilchik Field /Beluga&Tyonek Gas Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 9,060' 8,292' 8,959' 8,210' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16' 80' 80' Surface 3,521' 9-5/8" 3,521' 3,337' 5,750psi 3,090psi Intermediate Production 9,031' 5-1/2" 9,050' 10,640psi 7,480psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8" 6.4#/L-80 4,130' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Baker SABL-3/SLB tubing-retrievable ScSSSV 4,046'/162'MD and 3,815'/162'ND 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: • Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑✓ Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 12/4/2014 • Commencing Operations: ----, Oil ❑ Gas ❑., WDSPL ❑ Suspended 0 16.Verbal Approval: Date: iZ•y. I4 WINJ ❑ GINJ ❑ WAG p Abandoned 0 Commission Representative: G4 Sc- ...I'-1- GSTOR ❑ SPLUG 11117.I hereby certify that the foregoing is tr and correct to the best of my knowledge. Contact Taylor Nasse Email tnasseta7.hilcorp.com Printed Name a I r Nasse Title Operations Engineer Signature Phone 777-8354 Date I{ /3 / /1-1 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3\14— ce ''—E Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: 1 104,1 X Spacing Exception Required? Yes ❑ No IY Subsequent Form Required: /0— ci07 APPROVED BY I) Approved by: f COMMISSIONER THE COMMISSION Date: /2.-ii) /L.4f.( (oD //�� A I I Submit Form and Form 10-403(Rev ed 10/2012) r�@di�p lti�I sAlc for�7.�� crpt,i om?teafe 8f � / / achm n[ in Duplicate / 1 ` v v Lnt3L (�t 1 ? 45 /Z Well Prognosis Well: Falls Creek#6 tlileorp Alaska,LL Date: 12/3/2014 Well Name: Falls Creek#6 API Number: 50-133-20643-00 Current Status: Completed and Leg: perforated in T-20 Estimated Start Date: December 4, 2014 Rig: Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-137 First Call Engineer: Taylor Nasse (907) 777-8354 (0) (907)903-0341 (C) Second Call Engineer: Paul Chan (907)777-8333 (0) (907)444-2881 (C) AFE Number: 1413027C Estimated Bottom Hole Pressure: —3,770 psi at 8,690' TVD (Assumed 0.43 psi/ft gradient) Max. Anticipated Surface Pressure: —2,893 psi (0.10 psi/ft gas gradient) Brief Well Summary Falls Creek#6 is a grass roots well that is currently completed but not perforated. The well consists of 9-5/8" surface casing and 5-1/2" production casing with 2-7/8"tubing/packer completion. Objective of Work Add perforations in the Tyonek sands. - E-Line Procedure 1. MIRU e-line and pressure control equipment. PT lubricator to 250 psi low/3,500 psi high. Note that the well is pressurized with nitrogen. 2. If necessary, bleed nitrogen pressure down as requested by the RE to establish a drawdown on the formation. 3. Perforate the Tyonek sands with 2" 6 SPF 60 deg phased perf guns.All intervals are planned for 12 SPF so each will be shot twice. Depths are from the Halliburton reference GR/CCL/CBL dated 11 November, 2014. Send the correlation pass to Taylor Nasse and David Buthman for confirmation. Gross Proposed Perforated Intervals Sands Top (MD) Btm (MD) FT Tyonek T-8 ±6,302' ±6,322' ±20 4. POOH. 5. Flow well through test separator and record water and gas rates. 6. If any of the Tyonek sands are not commercial,then the zone will be plugged back with a bridge plug. 7. RD a-line. 8. Turn well over to production. t Well Prognosis Well: Falls Creek#6 llilcorp Alaska,Lb Date: 12/3/2014 Attachment: Proposed Wellbore Schematic Ninilchik Unit • Well: Falls Creek#6 PROPOSED COMPLETION PTD: 214-137 API: 50-133-20645-00 Hi!carp Alaska,LLC CASING DETAIL ��V I i Size Type Wt Grade Conn. ID Top Btm 16" 4/ .10,t _ " 16" Conductor 109 X-56 Weld 16" Surf 80' '." I � 9-5/8" Surf.Csg 40 L-80 BTC 8.835" Surf 3,521' 2 5-1/2" Prod Casing 17 P-110 CDC 4.892" Surf 9,050' Al TUBING ` 2-7/8" Production 6.4 L-80 EUE-8rd 2.441" Surf 4,130' S '1"4 44. N 5., %It ' TOC @ JEWELRY DETAIL ` ' z.. -.� 3,020' 4 '," 11: No. MD ND Item 9-5/8" 1 152' 152' CIM 401 4a `' a 2 162' 162' SLB TRMAXX SE SCSSSV w/2.312"Bore ti"r ' y4,a c' 3 4,046' 3,815' Baker SABL-3 Packer tthrk.` 4 4,130 3,892' Wireline re-entry guide ile 1Cefi# ,1,..:, ,,..._ �. r_.., . PROPOSED PERFORATION DETAIL ,'r Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) Ft Date Status ±5,581' ±5,625' ±5,218' ±5,258' ±44 Pending Proposed . , 1 ' T-1 ±5,659' ±5,705 ±5,289' ±5,331' ±46 Pending Proposed `' a ±5,739' ±5,798' ±5,362' ±5,416' ±59 Pending Proposed '►14' kl,'' ±5,843' ±5,851' _ ±5,457' _ ±5,464' ±8 Pending Proposed IFOI e T-2 ±5,917' ±5,943' ±5,524' ±5,548' ±26 Pending Proposed 8-1/2 "f y 3 P ±6,008' ±6,034' ±5,607' ±5,631' ±26 Pending Proposed Hole 1 "%„,d git, 1+ 'a. ±6,063' ±6,104' ±5,657' ±5,694' ±41 Pending Proposed ` *« � ±6,302' ±6,322' ±5,874' ±5,892' ±20 Pending Proposed* 5Ptr# 4 m ±6,722' ±6,739' ±6,256' ±6,271'1,4 ±17 Pending Proposed p * T-12 ±6,812' ±6,824' ±6,338' ±6,349' ±12 Pending Proposed *y T-20 ±7,300' ±7,350' ±6,785' ±6,827' ±50 11/24/14 Open ► *T-8 Sand is the only interval being requested-all other intervals previously approved. 0f itm T1 .,, T-2 Tah• ,r:. . T-6 ...w H . i"N+ T-8 if t �.�.arr, r . 11, t3lj T-12 jaill L'1" ..''''.1.` ".., 1-20 " r raaw..a.x *IE ' .,f 1 5.5" " PBTD=8,959'MD/8,210'TVD TD=9,060 MD/8,292'TVD Updated by DMA 12/03/14 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Thursday, December 04, 2014 3:00 PM To: 'Taylor Nasse' Cc: Chad Helgeson; Paul Chan Subject: RE: Falls Creek#6 10-403 Sundry(PTD 214-137) Taylor, As this perforation interval is additional to the previously approved sundry (314-617) and you are already on the wellsite with E-line you have verbal approval to proceed with perforating the T-8 sands. The Engineering staff has reviewed the request and find no issues with the proposed T-8 perf interval of 6302-6322' md. 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:Taylor Nasse [mailto:tnasse@hilcorp.com] Sent: Thursday, December 04, 2014 2:55 PM To: Schwartz, Guy L(DOA) Cc: Chad Helgeson; Paul Chan Subject: Falls Creek #6 10-403 Sundry(PTD 214-137) Guy- Hilcorp Alaska respectfully requests verbal approval to perforate the Tyonek T-8 sands from±6,302'—6,322' per the 10- 403 sundry that was submitted on 12/4/14(see attached for reference). Sincerely, Taylor W.Nasse,PE Operations Engineer Kenai Asset Team Hilcorp Alaska, LLC (907)777-8354 office (907)903-0341 cell 1 Seth Nolan Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive Anchorage, AK 99503 Tele: 907 777-8308 Hihnrp.thi k�, 1.1A Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATE 12/04/14 DATA LOGGED a/011201y M.K.BENDER To: Alaska Oil & Gas Conservation Commission Makana Bender RECEIVED Natural Resource Technician II 333 W 7th Ave Ste 100 n E r 0 5 2014 Anchorage, AK 99501 AOGCC DATA TRANSMITTAL Falls Creek 06 RCBL data Prints: Radial Cement Bond Log 5" Compensated Neutron Log 5" Elog data Prints: ROP DGR EWR 2"/5" MD DGR EWR 2"/5"TVD CD 1: digital version RCBL '25 t 3 q A Files Currently on the Disc (4) FALLSCREEK46_NEUTRON 11NOV14 11/14/2014 8:09 AM LAS File 7,624 KB 3 FALLSCREEK46_NEUTRON_UNO1/14 11/14/2014 8:09 AM TIFF image 10,778 KB FALLSCREEK46_RCBL 11NOV14 11/14/2014 8:08 AM LAS File 12,712 KB j�FALLSCREEIM_RCBL_11NOV14 11/14/2014 8:08 AM TIFF image 23,310 KB CD 2: digital version Elogs 2 S 5 5 CGM 12/4/2014 8:20 AM File folder },.. D[1S+LAS 12/4/2014 8:20 AM File folder EMF 12/4/2014 8:20 AM File folder j, PDF 12/4/2014 8:20 AM File folder j„ TIFF 12/4/2014 8:24 AM File folder Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Mxiizaeouti 6.4.44.4„ear: THE STATE A-fa (1'g's l _ �� = � of J v 1`\ L� 'i:,i e� i T' 221,c' � Vii• � \\ C? C�'.j,`;Yc`d'l:t�i:S. � �l; 16.!. '!i'. _ ------- — 333 West Seventh Avenue i GOVERNOR SEAN PARNE1 I_ Anchorage, Alaska 99501-3572 jp Main 907 279.1433 ALAS Fax: 907 276 7542 Taylor Nasse Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: Ninilchik Field, Beluga and Tyonek Gas Pools, Falls Creek#6 Sundry Number: 314-617 Dear Mr.Nasse: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P". Foerster Chair DATED this' eclay of November, 2014. Encl. RECEIVED STATE OF ALASKA NOV 14 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION CI- 0 g APPLICATION FOR SUNDRY APPROVALS j(��GG ! o I 1 li 20 AAC 25.280 a`' 1.Type of Request: Abandon❑ Plug for Redrill 0 Perforate New Pool❑ Repair Well❑ Change Approved Program ❑ Suspend❑ Plug Perforations❑ Perforate Q • Pull Tubing❑ lime Extension 0 Operations Shutdown 0 Re-enter Susp.Well ❑ Stimulate❑ Alter Casing❑ Other. ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Dnll Number. Hilcorp Alaska,LLC Exploratory ❑ Development 2 • 214-137 • 3.Address: Stratigraphic ❑ Service El6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-133-20645-00-00 7.If perforating: 8.Well Name and Number. i What Regulation or Conservation Order governs well spacing in this pool? C.O.701 Will planned perforations require a spacing exception? Yes ❑ No 2Falls Creek#6 . 9.Property Designation(Lease Number): 10.Field/Pool(s): re''..' I ADL 590(TPH)ADL384314(BHL) Ninilchik Field /Beluga&Tyonek Gas field' �� it, 1 7.,-/ 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 9,060' 8,292' 8,959' 8,210' N/A N/A — Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16' 80' 80' Surface 3,521' 9-5/8" 3,521' 3,337' 5,750psi 3,090psi Intermediate Production 9,031' 5-1/2" 9,050' 10,640psi 7,480psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8" 6.4#/L-80 4,130' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Baker SABL-3/SLB tubing-retrievable ScSSSV 4,046'/162'MD and 3,815'/162'ND 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑✓ Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 11/21/2014 Commencing Operations: Oil ❑ Gas El • WDSPL ❑ Suspended El 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG 111 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Taylor Nasse Email tnasset hilcorp.com Printed Name Taylor N se Title Operations Engineer Signature V //Phone 777-8354 Date d l//V /9 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: -,--4Spacing Exception Required? Yes ❑ No L� Subsequent Form Required: /t)-y c ? ( 'h6/ l ,t ' APPROVED BY Approved by /]/2 ��t�� COMMISSIONER THE COMMISSION Date: // / _ L/ L/ l /( ( t y ��1111 f 1 A I Submit Form and ABC_F slow p is1d 41 Approved appllcaO Ride�apt s(rL the date of approval. Attachments in Duplicate IVVUU�Y ;i(Gl tvJ �J 1 , �G ` /Me //./7 /V Well Prognosis Well: Falls Creek#6 Hilcorp Alaska,LL Date: 11/12/2014 Well Name: Falls Creek#6 API Number: 50-133-20643-00 Current Status: Completed, not Leg: perforated Estimated Start Date: November 20, 2014 Rig: Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-137 First Call Engineer: Taylor Nasse (907) 777-8354(0) (907) 903-0341 (C) Second Call Engineer: Paul Chan (907)777-8333 (0) (907)444-2881 (C) AFE Number: 1413027C Estimated Bottom Hole Pressure: —3,770 psi at 8,690' ND (Assumed 0.43 psi/ft gradient) Max. Anticipated Surface Pressure: —2,893 psi (0.10 psi/ft gas gradient) Brief Well Summary Falls Creek#6 is a grass roots well that is currently completed but not perforated. The well consists of 9-5/8" surface casing and 5-1/2" production casing with 2-7/8"tubing/packer completion. Objective of Work Initial perforations in the Tyonek sands. E-Line Procedure 1. MIRU a-line and pressure control equipment. PT lubricator to 250 psi low/3,500 psi high. Note that the well is pressurized with nitrogen. 2. If necessary, bleed nitrogen pressure down as requested by the RE to establish a drawdown on the formation. 3. Perforate the Tyonek sands with 2" 6 SPF 60 deg phased perf guns. All intervals are planned for 12 SPF so each will be shot twice. Depths are from the Halliburton reference GR/CCL/CBL dated 11 November, 2014. Send the correlation pass to Taylor Nasse and David Buthman for confirmation. Gross Proposed Perforated Intervals Sands Top(MD) Btm (MD) FT Tyonek T-1 ±5,581' ±5,625' ±44 Tyonek T-1 ± 5,659' ±5,705 ±46 Tyonek T-1 ± 5,739' ±5,798' ±59 Tyonek T-2 ±5,843' ±5,851' ±8 Tyonek T-2 ±5,917' ±5,943' ±26 Tyonek T-6 ±6,008' ±6,034' ±26 Tyonek T-6 ±6,063' ±6,104' ±41 Well Prognosis Well: Falls Creek#6 Ililcorp Alaska,Lb Date: 11/12/2014 Tyonek T-12 ±6,722' ±6,739' ±17 Tyonek T-12 ±6,812' ±6,824' ±12 Tyonek T-20 ±7,270' ±7,352' ±82 4. POOH. 5. Flow well through test separator and record water and gas rates. 6. If any of the Tyonek sands are not commercial,then the zone will be plugged back with a bridge plug. 7. RD e-line. 8. Turn well over to production. Attachment: Current and Proposed Wellbore Schematic Ninilchik Unit 1]_ Well: Falls Creek#6 CURRENT COMPLETION PTD: 214-137 API: 50-133-20645-00 CASING DETAIL i Size Type Wt Grade Conn. ID Top Btm 16 th 16" Conductor 109 X-56 Weld 16" Surf 80' 9-5/8" Surf.Csg 40 L-80 BTC 8.835" Surf 3,521' 1 5-1/2" Prod Casing 17 P-110 CDC 4.892" Surf 9,050' 2 TUBING 2-7/8" Production 6.4 L-80 EUE-8rd 2.441" Surf 4,130' TOC @ JEWELRY DETAIL 3,020' . No. MD TVD Item 9-5/8"' `, .'' 1 152' 152' CIM 2 162' 162' SCSSSV ' 3 4,046' 3,815' Baker SABL-3 Packer 4 4,130' 3,892' Wireline re-entry guide tom ." Ai k 8-1/2" . 8, , Hole 3 = .. -i►i `w 4 9k- ?? i (y e ,f•:411 itp .„ i : 1,4 04 „441 1r 5.5" +. , A .,-. I .#+ PBTD=8,959'MD/8,210'ND TD=9,060 MD/8,292'ND Updated by DMA 11/14/14 Ninilchik Unit Well: Falls Creek#6 . - H PROPOSED COMPLETION PTD: 214-137 API: 50-133-20645-00 Hilcorp Alaska,LLC CASING DETAIL - i ' Size Type Wt Grade Conn. ID Top Btm 16"49 N' 16" Conductor 109 X-56 Weld 16" Surf 80' " 9-5/8" Surf.Csg 40 L-80 BTC 8.835" Surf 3,521' .', •r 5-1/2" Prod Casing 17 P-110 CDC 4.892" Surf 9,050' - TUBING 2-7/8" Production 6.4 L-80 EUE-8rd 2.441" Surf 4,130' r TOC @ JEWELRY DETAIL x 3,020' . No. MD TVD Item 9-5/8 •' s. 1 152' 152' CIM / , . ,•• 2 162' 162' SCSSSV 3 4,046' 3,815' Baker SABL-3 Packer 4 4,130' 3,892' Wireline re-entry guide PROPOSED PERFORATION DETAIL i4-1', v. Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) Ft Date Status ±5,581' ±5,625' ±5,218' ±5,258' ±44 Pending Proposed I' '' T-1 ±5,659' ±5,705 ±5,289' ±5,331' ±46 Pending Proposed ' ±5,739' ±5,798' ±5,362' ±5,416' ±59 Pending Proposed T-2 ±5,843' ±5,851' ±5,457' ±5,464' ±8 Pending Proposed 8 ±5,917' ±5,943' ±5,524' ±5,548' _ ±26 Pending Proposed Hole" 3 T 6 ±6,008' ±6,034' ±5,607' ±5,631' ±26 Pending Proposed ±6,063' ±6,104' ±5,657' ±5,694' ±41 Pending Proposed ±6,722' ±6,739' ±6,256' ±6,271' ±17 Pending Proposed ' - • T-12 4 ±6,812' ±6,824' ±6,338' ±6,349' ±12 Pending Proposed T-20 ±7,270' ±7,352' ±6,755' ±6,829' ±82 Pending Proposed r .,r r T-1 r �' 4* T-2 _ T-6 ` T-12 4_- t- T-20 5.5" °Li._ y PBTD=8,959'MD/8,210'TVD TD=9,060 MD/8,292'ND Updated by DMA 11/14/14 2-12A- ke-57 �v�\\\I/I/� lSs, 'Flit o'l Ai t / A-:',,m;.c.:, C:! I J'P1 r'J._I,l,d ,L-.,C;u s� _ '' - --- ------- --- 333 Wr:si 5( vcri10 A✓unuu r.;_ -!-:;----1-----',,,` ' ix()�'I llti,)1: S1;-\N �',\lt�'1'I i Aric0oiage A[uska 99501 35/2 '`� 1 ,nin 9 ,/ 2i9 14'?, Paul Chan Senior Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Ninilchik Field, Beluga& Tyonek Gas Pool, Falls Creek#6 Sundry Number: 314-582 Dear Mr. Chan: 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, 0 t � Daniel T. Seamount, Jr. Commissioner DATED this-day of November, 2014. Encl. A `C IV E D STATE OF ALASKA OF- T ) '4 7 014 ALASKA OIL AND GAS CONSERVATION COMMISSION ( Sri APPLICATION FOR SUNDRY APPROVALS �� ' ,�'��+ 101114 20AAC25.280 'A'�) '(' 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well 0 Change Approved Program ❑ Suspend❑ Plug Perforations ❑ Perforate ❑ Pull Tubing❑ Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate ❑ Alter Casing❑ Other. Complete D• 2.Operator Name. 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development Q • 214-137 • 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-133-20645-00-00 • 7. If perforating. 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O. 701 Will planned perforations require a spacing exception? Yes 0 No ❑l Falls Creek#6 9.Property Designation(Lease Number). 10.Field/Pool(s): ADL 590 (TPH)-ADL384314 (BHL) • Ninilchik Field /Beluga&Tyonek Gas Field . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): ±9,700'(Planned) N/A N/A N/A N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16' 80' 80' Surface 3,521' 9-5/8" 3,521' 3,337' 5,750psi 3,090psi Intermediate 8,767' 5-1/2" ±9,679'(Planned) 10,640psi 7,480psi Production Liner I Perforation Depth MD(ft): 'Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Separate 10-403 will be submitted for the initial perforations 2-7/8" L-80/6.4#/ft See Schematic Packers and SSSV Type. Packers and SSSV MD(ft)and TVD(ft): See Schematic See Schematic 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: • Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑✓ Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 11/5/2014 Commencing Operations: Oil 0 Gas Q . WDSPL ❑ Suspended 0 16.Verbal Approval: Date: WINJ 0 GINJ ❑ WAG 0 Abandoned ❑ Commission Representative: GSTOR 0 SPLUG 0 17. I hereby certify that the foregoing is true . d correct to the best of my knowledge. Contact Paul Chan Email pchanahilcorp.com Printed Nam- P-ul Alli- Title Senior Operations Engineer Signature A. Phone 777-8333 Date 10/29/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: i-{.^ Plug Integrity 0 BOP Test Mechanical Integrity Test ❑ Location Clearance 0 Other. 4- 3.5c-0 p . ;/ 77, -t- ( y - (cipeve` 3 p} 41, 5 P) ,-- 07 LJ�c-(' qi Spacing Exception Required? Yes 0 No Er Subsequent Form Required: / 0 ' 1 `,J/�/ APPROVED BY Q. Approved by. Ii / COMMISSIONER THE COMMISSION Date: ( I I �I 6r - Form Submit Form and Form 10-403(Bevis 01Apr all i t f r 12 months from the date of approval. Attachments Duplicate RBE S NOV - 6 1�,' i� 0/ fi/ ,-4,-:40ic,-3vest a Well Prognosis Well: Falls Creek#6 Hilcorp Alaska,LU Date: 10/29/2014 Well Name: Falls Creek#6 API Number: 50-133-20643-00 Current Status: Drilling Production Hole Leg: Estimated Start Date: November 5, 2014 Rig: Saxon 147 Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-137 First Call Engineer: Paul Chan (907) 777-8333 (0) (907) 345-3161 (H) (907)444-2881 (C) Second Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228(C) AFE Number: 1413027C Estimated Bottom Hole Pressure: -3,770 psi at 8,690' TVD (Assumed 0.43 psi/ft gradient) Max.Anticipated Surface Pressure: -2,893 psi (0.10 psi/ft gas gradient) Brief Well Summary Falls Creek#6 is a grass roots welled currently being drilled by the Saxon 147 rig. 9-5/8" surface casing has been set and the rig is drilling the 8-1/2" hole section. After the production casing is run and cemented,Saxon 147 will run the 2-7/8" completion. Objective of Work Complete the well with 2-Y8"tubing and jewelry with the Saxon 147 rig. RDMO the rig. Completion Procedure: E and any-Spa recspools. `« 2.�1 U�ubing spool and DSA. / t''l„ 3. -N-U-B Rf. r`, 4. Change over to 2-7/8" x 5-1/2"VBR. Test all breaks and VBR with a 2%s"test joint to 250 psi low/ 3,500 psi high. LD test joint. 5. PU bit and scraper for 5-1/2" 17#casing on 2-%"tubing string. Rabbit the tubing before RIH 6. RIH and reciprocate scraper across packer set depth by making a 4 stand short trip. Depths for short trip will be forwarded after evaluating the open hole logs. Continue RIH to PBTD and circulate the hole clean at maximum rate. 7. POOH and stand back tubing. 8. Depending upon the open hole log interpretation,the production packer approximate set depth will be either^'3,500' MD (shallow)or^7,600' MD(deep): a. If the packer is set shallow,then the cased hole e-line logging will be run post-rig, b. If the packer is set deep,then MIRU e-line. PT to 250 psi low/3500 psi high. c. Run GR/CCL/CBL/Neutron logs : i. Run Neutron log from PBTD to 3521' MD. Well Prognosis Well: Falls Creek#6 Hilcorp Alaska,LU Date: 10/29/2014 ii. Run GR/CCL from PBTD to surface. All 5-1/2" casing/tubing details should be notated on the log(RA tags and marker joints if any. See casing/cementing report for details). iii. Run CBL cement bond log with GR/CCL from PBTD to 3021' MD(500' above 9-5/8" shoe). Depending upon results from the initial CBL run, a pressure pass may also be required. d. RDMO e-line 9. Prepare to PU tubing. Run 2-7/8' 6.4#L-80 tubing w/packer and 2-%8"tailpipe as detailed below. Rabbit the tubing and jewelry before RIH. RU control line spoolers as needed. • 2%8"WLEG. Depth to be determined. • 1 joint 2-%8" 6.4#L-80 tubing • 2-7/8"X nipple with RHC-P ball catcher • 1 joint 2-%" 6.4# L-80 tubing • 5-1A" x 2-%8' Hydraulic set packer w/handling pups. Packer set depth ±3,500'or±7,600' MD • 2%8" 6.4# L-80 tubing • 2-%8" 6.4#L-80 handling pup • 2-7/8' SCSSSV @ —170' MD • 2-7/8' 6.4# L-80 handling pup • 2-7/8' 6.4#L-80 handling pup • 2-7/8' Chemical injection sub @ "'157' MD • 2-7/8' 6.4# L-80 handling pup • 4 joints 2%8" 6.4# L-80 tubing • Tubing hanger with handling pup 10. RIH with completion. Record PU and SO weights. 11. MU tubing hanger, control lines, and landing joint. Test control line for SSSV to 6000 psi. 12. Land tubing hanger and RILDS. LD landing joint. Test tubing hanger packoff. 13. Reverse circulate in 8.6 ppg KCI brine with 0.5 gal/bbl of corrosion inhibitor. 14. Drop ball/rod. Pressure up on the tubing and set the packer. 15. Test tubing to 3,500 psi for 30 min. Bleed off pressure to 1500 psi. eY/ 16. Test the IA to 2,000 psi for 30 min. Bleed off IA. 17. Set TWC. ND BOPE. NU adapter flange and tree. PT tree. RU lubricator and pull TWC. Slickline Procedure 18. MIRU slickline 19. Pull ball/rod. POOH. 20. Retrieve RHC-P. POOH. 21. Drift tubing/casing to maximum depth. POOH. . , li Well Prognosis Well: Falls Creek#6 Hilcorp Alaska,LL Date: 10/29/2014 22. RDMO. E-Line Procedure (if not already run) 23. MIRU e-line. PT to 250 psi low/3500 psi high. 24. Run GR/CCL/CBL/Neutron logs: a. Run Neutron log from PBTD to"'3521' MD. b. Run GR/CCL from PBTD to surface. All 5-1/2" casing/tubing details should be notated on the log(RA tags and marker joints if any. See casing/cementing report for details). c. Run CBL cement bond log with GR/CCL from PBTD to 3021' MD (500' above 9-5/8" shoe). Depending upon results from the initial CBL run, a pressure pass may also be required. 25. RDMO e-line Coiled Tubing Procedure 26. RU CTU, nitrogen, and flow back tanks. Notify AOGCC 24 hours prior to testing at http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html 27. Shell test BOPE/lubricator to 250psi low/4,500psi high (unless due for weekly BOPE test—then a full BOPE test will be done). 28. RIH with CT and blow the well dry with nitrogen. Strap tank before and after blowing the well down. 29. Leave well with N2 cap. POOH. 30. RDMO CTU. E-Line Procedure- Perforating 31. A separate Form 10-403 will be submitted for the initial perforations on this well. Attachment: Current(drilling)and Proposed Wellbore Schematic Ninilchik Unit Lu rre ntly Drilling Well: Falls Creek#6 II PTD: 214-137 API: 50-133-20645-00 Hilcarp Alaska,LLC CASING DETAIL 4?1: ►` Size Type Wt Grade Conn. ID Top Btm 16" 16" Conductor 109 X-56 Weld 16" Surf 80' 9-5/8" Surf. Csg 40 L-80 BTC 8.835" Surf ±3,521' 5-1/2" Prod Casing 17 P-110 CDC 4.892" Surf ±9,679' 47 y 1 *" TOCat 9-5/8" 44"r . 3000' I f spa. eJFA *r k r w ,I . . . "` k 's'' 8-1/2" ,. i " Hole 4 * ' '0-f,''*' 1414:110101 0 "e. tillik ,44y Ott+."'s tli(41 .ryr Xq k I :a JO 1. 4 to . f 10A; 4t L At 41 '$ 1 i 5.5 ‘..... �1 Planned PBTD=9,500'MD/8,625'TVD TD=9,679 MD/8,767'TVD Updated by PC 10/28/2014 . Ninilchik Unit Proposed Completion Well: Falls Creek#6 PTD: 214-137 API: 50-133-20645-00 1lilrorp Alaska,LLC CASING DETAIL j'' '; Size Type Wt Grade Conn. ID Top Btm 16" .4. * ;" 16" Conductor 109 X-56 Weld 16" Surf 80' 9-5/8" Surf. Csg 40 L-80 BTC 8.835" Surf ±3,521' 5-1/2" Prod Casing 17 P-110 CDC 4.892" Surf ±9,679' ;r: TUBING -, 2-7/8" Production 6.4 L-80 EUE-8rd 2.441" Surf iii *• TOC at 9-5/8" ' c ' k''..r. " 3000' i _` I 4 � _ JEWELRY DETAIL '4 No. MD ND Item " +�, 1 ± 157' ± 157' CIM 3 '• i ,14,11'114 it#Pli 2 ± 170' ± 170' SCSSSV i4,110k V ' ±3,500' ±3,050' Prod Packer set depth to be confirmed 'Lt 3 or or after drilling and logging production y ±7,600' ±6,800' hole section + " ' 4 Wireline re-entry guide Hole 3 IV "b4 , . ' c ,i 4ifis .161J — TN, 4. �xxR 4 44,4 �G r' .9 euu a' ' 1; r rr. 4)12 41 41 t414 l. 5.5" d ;''' S iiii Planned PBTD=9,500'MD/8,625'TVD TD=9,679 MD/8,767'TVD Updated by PC 10/28/2014 41. Schwartz, Guy L (DOA) From: Paul Chan <pchan@hilcorp.com> Sent: Tuesday, November 04, 2014 8:46 AM To: Schwartz, Guy L(DOA) Cc: Luke Keller;James Lott - (C); Doug Yessak - (C); Clint Chantey; Taylor Nasse; Chad Helgeson Subject: RE: Falls Creek#6 10-403 Submittal (PTD 214-137) Attachments: Falls Creek#6 wellhead tree schematic.pdf Guy The MBS has not changed from the PTD application. Thanks Paul Chan Senior Operations Engineer Kenai Asset Hilcorp Alaska LLC (907) 777—8333 (w) (907)444—2881 (c) (907) 345—3161 (h) From: Schwartz, Guy L (DOA) [ ailto:guy.schwartz@lalaska.gov] Sent: Tuesday, November 04, 2014 8:40 AM To: Paul Chan Cc: Luke Keller; James Loft - (C); Doug Yessak - (C); Chad Helgeson; Clint Chantey; Taylor Nasse Subject: RE: Falls Creek #6 10-403 Submittal (PTD 214-137) Paul, Will delete steps 1-3 in the Sundry request. Can you forward a diagram of the MBS wellhead if it is different than was proposed in the PTD application. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: nis 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: Paul Chan [mailto:pchan@hilcorp.com] Sent: Tuesday, November 04, 2014 7:53 AM To: Schwartz, Guy L (DOA) Cc: Luke Keller; James Lott - (C); Doug Yessak - (C); Chad Helgeson; Clint Chantey; Taylor Nasse Subject: Falls Creek #6 10-403 Submittal (PTD 214-137) Guy The wellhead system on the Falls Creek#6 well has been upgraded to a multi-bowl system (MBS). With a MBS,the 2- 7/8" production tubing can be run without having to ND the BOPE as the tubing spool is already part of the wellhead system. Hilcorp Alaska respectfully requests to delete steps 1-3 in the completion procedure. Attached is the 10-403 submittal for the well for your reference. Thanks Paul Chan Senior Operations Engineer Kenai Asset Hilcorp Alaska LLC (907)777—8333 (w) (907)444—2881 (c) (907)345—3161 (h) 2 Falls Creek#6 Drilling Procedure Hilcorp EnergY ComPatly 21.0 Wellhead Schematic Ninilchik Unit New drill system-Seaboard Saxon Rig 147 16 x95/8 x51/2 tt rp• 1111 ISM I I . r.■ 4.e (S) U CJ METZUI III: : D i_s (e■__ Tubing head,Seaboard-S8, 11 5M X 7 1/16 5M, w/2-2 1/16 5M SSO, : 0� 5 i 7"P seal bottom . (- ! p. • ,rats— Wit T II !:! " Casing spool,Seaboard-S8, , 16 3/4 3M X 11 5M, �el w/2-2 1/16 5M SSO, 11_1 - o�� 1 t.1.t' 9 5/8 P seal bottom - ril t t. �i 0 ti-r=1;era. Starting head,Seaboard, i* 16%3M X16"SOWBTM, I w/2-2 1/16 5M SSO ;� ; C` 2 j ��. i C C' i ( ! l� i n � i 16" 7 9 5/8" 5%" Page 37 Version 2 Sept, 2014 A�\� I7�i::4\ THE STATE hr3L ' ; � ., r-_-� CJ as F —`of`'`t'` /- _- `It s#tf _ - J -- 333 Wes; Sevenli, Avct ue `*� /1 ( 0V1,1ZNOR SEAN P Altti'I=! !- 3,nch,.oraae Alaska 99501-3572 \--PL,--\ - irri'f) n07 279 1 4'3 3 h 1L,F.,u/ Luke Keller Drilling Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Ninilchik Field, Beluga/Tyonek Gas Pool, Falls Creek*(jz. Hilcorp Alaska, LLC Permit No: 214-137 Surface Location: 1906' FSL, 2730' FEL, SEC. 6, T1N, R12W, SM,AK Bottomhole Location: 38' FSL, 857' FWL, SEC. 31,T2N, R12W, SM, AK Dear Mr. Keller: Enclosed is the approved application for permit to drill the above referenced development well. 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 Hilcorp Alaska, LLC in the attached application, the following well logs are also required for this well: A gamma ray log must be recorded across the surface hole interval. A cased-hole gamma ray log is acceptable. 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 an approval 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. 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 a AOGCC order,or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, / / 4e16 -- Cathy P. Fo•rster Chair DATED this L day of October, 2014. RECEIVE® STATE OF ALASKA SEP 2 5 2014 AL, A OIL AND GAS CONSERVATION COMM; N PERMIT TO DRILL �EVI'S , 1 � (1, C 20 AAC 25.005 I'd 1 a.Type of Work: 1 b. r se e I Class: Development-Oil ❑ Service- Winj ❑ Single Zone 0 lc.Specify if well is proposed for: Drill ❑, • Lateral 0 Stratigraphic Test ❑ Development-Gas❑, - Service-Supply El Multiple Zone ❑✓ • Coalbed Gas 0 Gas Hydrates 0 Redrill❑ Reentry 0 Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal El Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Q . Single Well ❑ 11.Well Name and Number: Hilcorp Alaska,LLC Bond No 022035244 • Falls Creek#6• 3.Address: 6.Proposed Depth: 12 Field/Pool(s): 3800 Centerpoint Drive,Suite 1400,Anchorage AK 99503 MD: 9,679' . TVD. 8,767, Ninilchik 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Beluga/Tyonek Gas Pool Surface: .1906'FSL,2730'FEL,Sec 6,TIN,R12W,SM,AK • ADL 590(TPH)ADL384314(BHL)) -7• 7-1014-r---iCO 701 Top of Productive Horizon: 8.Land Use Permit: /"ij ,iyG 13 Approximate Spud Date: 2535'FNL,2084'FWL,Sec 6,TIN,R12W,SM,AK NA 10/24/2014 • Total Depth: 9.Acres in Property: 14 Distance to Nearest Property: 38'FSL,857'FWL,Sec 31,T2N,R12W,SM,AK ADL590=564.45;ADL384314=3518.45 82'from Unit Tract 49A(within PA) 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: i 266.9 feet 15.Distance to Nearest Well Open Surface. x-240096.8 • y-2269464.23 • Zone-4 GL Elevation above MSL: • 248.3 feet to Same Pool: 3,386' 16.Deviated wells: Kickoff depth: 500 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25 035) Maximum Hole Angle: 38 degrees • Downhole: 3770 psi • Surface: 2893 psi • 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD 1 TVD (including stage data) Cond 16" 109 X-56 Weld 80' Surf Surf 80' 80' f Driven 12-1/4" 9-5/8" 40 L-80 BTC 3,500' Surf Surf 3,500' • X2$11 3t'j f4,., 313.4bb1/331ft3 8-1/2" 5-1/2" 17 P-110 CDC 9,679' Surf Surf 9,679' 8,767' 352.8bb1/1944.5ft3 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat Q BOP Sketch Q Drilling Program 0 Time v.Depth Plot Q Shallow Hazard AnalysisEl Diverter Sketch Q Seabed Report 0 Drilling Fluid Program 0 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Luke Keller Email Ikeller(c�hilcorp.com Printed Name Luke K ler ::ne :i:::::er Sure Date 9/25/2014 Commission Use Only Permit to Drill —a API Number. Permit Approval See cover letter for other Number: -fes 50-1�3'ZO&V,SzC/ Date: ED i y 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: g Other x 3 S c 0 p5` 8L,in t Samples req'd: Yes❑ No[.1 Mud log req'd.Yes❑ o[" H2S measures: Yes❑ Nog Directional svy req'd.Yes'NNo❑ 41 C g L ,,--e2,.,„.„-,,,j,/ Spacing exception req'd: Yes❑ No t/ Inclination-only svy req'd.Yes❑ No[Z T 5r.K7r - - SL,4-L` , 1 4 C v 1-11.n r.).< '�'L I0 1 cd r Y L�y r APPROVED BY Approved by: ifs1 ~ S IONE THE COMMISSION Date' 10-/-/ .1 I _ L (".3 t I Submit Form and Form 10-401(Revised 10/2012)/ This permit is valid for 24 mo f t d t o p (20 AAC '5,,0,0 (8)) Attachments in Duplicate 3anise Barrett Hilcorp Alaska, LLC Drilling Technician P.O. Box 244027 Anchorage,AK 99524-4027 Tel 907 777 8389 Email jbarrett@hilcorp.com Aileorp Al,i ke,LLC 9/25/14 Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 RECEIVED Re: Falls Creek#6 Revision P: 25 ?014 Dear Commissioner, (,)k,:i'� � Enclosed for review and approval is a revision to the application for the Permit to Drill the Falls Creek#6 development gas well. The surface location was changed. If you have any questions, please don't hesitate to contact the drilling engineer Luke Keller at 777- 8395 or Paul Maz7olini at 777-8369. Sincerely, _ 1`�- "Mow Janise Barrett Drilling Technician Hilcorp Alaska, LLC Page 1 of 1 Hilcorp Alaska, LLC Falls Creek #6 Drilling Program Version 2 / Sept 24th, 2014 Falls Creek#6 Drilling Procedure Hilcorp Energy Company Contents 1.0 Well Summary 2 2.0 Management of Change Information 3 3.0 Tubular Program: 4 4.0 Drill Pipe Information: 4 5.0 Internal Reporting Requirements 5 6.0 Planned Wellbore Schematic 6 7.0 Drilling/Completion Summary 7 8.0 Mandatory Regulatory Compliance/Notifications 8 9.0 R/U and Preparatory Work 10 10.0 N/U 21-1/4"2M Diverter System 11 11.0 Drill 12-1/4" Hole Section 13 12.0 Run 9-5/8"Surface Casing 17 13.0 Cement 9-5/8" Surface Casing 20 14.0 BOP N/U and Test 23 15.0 Drill 8-1/2" Hole Section 24 16.0 Run 5-1/2"Production Casing 29 17.0 Cement 5-1/2" Production Casing 32 18.0 RDMO 35 19.0 Perf and Frac 35 20.0 BOP Schematic 36 21.0 Wellhead Schematic 37 22.0 Days Vs Depth 38 23.0 Formation Tops 39 24.0 Anticipated Drilling Hazards 40 25.0 Saxon Rig 147 Layout 42 26.0 FIT Procedure 43 27.0 Choke Manifold Schematic 44 28.0 Casing Design Information 45 29.0 8-1/2"Hole Section MASP 46 30.0 Spider Plot(NAD 27)(Governmental Sections) 47 31.0 Surface Plat(As Staked)(NAD 27) 48 32.0 Offset MW vs TVD Chart 49 Falls Creek#6 Drilling Procedure Hilcorp Energy Company 1.0 Well Summary Well Falls Creek#6 Pad Falls Creek Planned Completion Type 2-7/8"prod tubing inside 5-1/2"production casing Target Reservoir(s) Beluga 135,Tyonek, T-8, T-10, T-50, T-60, T-65 Planned Well TD,MD/TVD 9,679' MD/ 8,767' TVD PBTD, MD/TVD 9,500' MD/ 8,625' TVD Surface Location(Governmental) 1906' FSL,2730' FEL, Sec 6, T1N,R12W, SM,AK Surface Location(NAD 27) X=240096.8,Y=2269464.23 Surface Location(NAD 83) Top of Productive Horizon (Governmental) 2535'FNL,2084'FWL, Sec 6,T1N,R12W, SM,AK TPH Location(NAD 27) X=239704.75,Y=2270305.09 TPH Location(NAD 83) BHL(Governmental) 38'FSL, 857'FWL, Sec 31,T2N,R12W, SM,AK BHL(NAD 27) X=238534,Y=2272904 BHL(NAD 83) AFE Number 1413027D AFE Drilling Days 32 AFE Completion Days AFE Drilling Amount $5,425,934 AFE Completion Amount Maximum Anticipated Pressure (Surface) 2893 psi(100%evacuation to 0.1 psi/ft gradient) Maximum Anticipated Pressure (Downhole/Reservoir) 3770 psi Work String 4-1/2" 16.6# S-135 CDS-40 KB Elevation above MSL: 248.3' + 18.6' =266.9' GL Elevation above MSL: 248.3' NAVD88 BOP Equipment 11"5M T3-Energy Annular BOP 11"5M T3-Energy Double Ram 11"5M T3-Energy Single Ram Page 2 Version 2 Sept, 2014 Falls Creek#6 Drilling Procedure Hilcorp Energy Company 2.0 Management of Change Information Hilcorp Alaska, LLCitca p Changes to Approved Permit to Drill Date: Subject Changes to Approved Permit to Drill for Falls Creek#6 File#: Falls Creek #6 Drilling and Completion Program Any modifications to Falls Creek#6 Drilling&Completion Program will be documented and approved below. Changes to an approved APD will be Giomelpinivatatte.1be BLM and AOGCC. Sec Page Date Procedure Change Approved Approved By By Approval: Drilling Manager Date Pre pared: Drilling Engineer Date Page 3 Version 2 Sept, 2014 Falls Creek#6 Drilling Procedure Hilcorp Energy Comwny 3.0 Tubular Program: Hole OD (in) ID (in) Drift Conn Wt Grade Conn Burst Collapse Tension Section I (in) OD(in) (#/ft) (psi) (psi) (k-lbs) Cond 16'' 15" - - 109 X-56 Weld 12-1/4" 9-5/8" 8.835" 8.75" 10.625" _ 40 L-80 BTC 5750 3090 916 8-1/2" 5-1/2" 4.892" 4.767" 6.05" 17 P-110 CDC 10600 8730 545 L 4.0 Drill Pipe Information: Hole OD (in) ID (in) TJ ID TJ OD Wt Grade I Conn Burst Collapse Tension Sectiop .., (in) (in) (#/ft) (psi) (psi) (k-lbs) All 4.5" 3.826 2.6875" 5.25" 16.6 S-135 CDS40 17,693 16,769 468k All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 4 Version 2 Sept, 2014 Falls Creek#6 II T Drilling Procedure Hilcorp Enemy Company 5.0 Internal Reporting Requirements 5.1 Fill out daily drilling report and cost report on Wellez. • Report covers operations from 6am to 6am • Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area—this will not save the data entered, and will navigate to another data entry tab. • Ensure time entry adds up to 24 hours total. • Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. 5.2 Afternoon Updates • Submit a short operations update each work day to pmazzolini@,hilcorp.com , lkeller@hilcorp.com and jbarrett@hilcorp.com 5.3 Intranet Home Page Morning Update • Submit a short operations update each morning by 7am on the company intranet homepage. On weekend and holidays, ensure to have this update in before 5am. Each rig will be assigned a username to login with. 5.4 EHS Incident Reporting • Notify EHS field coordinator. 1. This could be one of(3) individuals as they rotate around. Know who your EHS field coordinator is at all times, don't wait until an emergency to have to call around and figure it out!!!! a. John Coston: 0: (907) 777-6726 C: (907)227-3189 b. Mark Tornai: 0: (907)283-1372 C: (907) 748-3299 c. Thad Eby: 0: (907) 777-8317 C: (907)602-5178 2. Spills: Kate Kaufman: 0:907-777-8329 C:907-244-8292 • Notify Drlg Manager 1. Paul Mazzolini: 0: 907-777-8369 C: 907-317-1275 • Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally • Send final"As-Run"Casing tally to lkeller@hilcorp.com and jbarrett@hilcorp.com 5.6 Casing and Cmt report • Send casing and cement report for each string of casing to lkeller@hilcorp.com and jbarrett@hilcorp.com Page 5 Version 2 Sept, 2014 Falls Creek#6 iii Drilling Procedure Hilcorp Energy Company 6.0 Planned Wellbore Schematic CASING DETAIL 1 . `4 I LMud Ll Type WY. Grade Conn. ID Top Btm Weight conductor— c , ? DtiVefl to Set 1.09 X-56 Weld _: Surf B0' Depth E Surf.Csg 42 L-50 BTC 5.525- Surf 3500' 5.5 pog Brod casing 7 P-112 CDC. 4. ;Z Surf 9,679' 5 pot I TUBING abs _ Production 5.4 L-60 157 Z.44 Sc•f 5.1222.' e r 9413" 4y - " . TOC at Drillirg Irfo Hole Section Casing f:.", 'rYgrkS[rg 12-1/4" 9-5/8' 5.5 ppg 4-1/2` 5-1/2' 5-1,1.2' E.5 PPg 4-1'2. JEWELRY DETAIL 1%:•-:.• Depth ID OD Item 1.54 scssi t'- 4800' CIM • = 5040 Prod Pkr 5022 Wireline re-entry guide I1 8-1/2" k`e �z • Hole 6 Planned Reservoir Objectives ,.,. $ Zone Top I MD1 Top(TVD' Est Pressure .`.". Gradient i Beluga 135 5,461 4,906 211.0 5.27 0.43 14: 6 Ty one's 5,748 5,1.59 2,218 5.27 0.45 - 7-5 6,566 5,652 2,529 5.5' 0.45 7-10 6,655 6,164 2,65: 5.27 0.45 7-55 6,229 7,446 ?,203 6.27 0.43 .. T-40 8,453 7,671 3,299 8.27 0.43 y, , ' 7-65 6,666 6,075 .,4'2 8.27 0.43 A T 1 's' ?' PBTD=9,504'AID.8,625'TAD TD=9,679 MID?8,767'TVD Page 6 Version 2 Sept, 2014 Falls Creek#6 Drilling Procedure Hilcorp Energy Company 7.0 Drilling / Completion Summary Falls Creek#6 is a 9679'MD Tyonek and Beluga gas development well planned to be drilled from the existing Falls Creek pad. Subsurface and 3D seismic control indicate flat structure to the northeast of the Falls Creek 1RD,which has cumulated over 20 BCFG from predominately the Tyonek Formation. In addition, seismic indicates a T-50/T-60 stratigraphic thick--similar to that observed in the recently completed Frances 1 well in the same reservoir unit. In addition, an AVO anomaly has been mapped at the T-60 take point. The wellbore is planned as a build and hold wellbore with a shallow kick off at 500' to gain separation from the existing wells on the pad. Maximum hole angle will be 38 degrees near TD. Drilling operations are expected to commence approximately Oct 20, 2014. ' The Saxon Rig# 147 will be used to drill the well and run the 5-1/2"long string. All known potential fresh water zones exist above 200'. This information is based off salinity calculations of neighboring water wells. Chlorides are 1100 ppm at the 171 — 194' sand, 1800 ppm at the 505 — 535' / sand, and 6000 ppm at the 1040' sand. Furthermore, the TGAS (total gas) curve from offset mud logs begins registering shallow gas at depths just below the sandstone bed at 200'. • Surface casing will be run to 3,500' MD /3,316' TVD and cemented to surface to ensure protection of these resources. Cement returns to surface will confirm TOC at surface./If cmt returns to surface are not observed, a Temp log will be run between 6 — 18 hrs after CIP to determine TOC. Necessary remedial action will then be discussed with AOGCC authorities. All waste &mud generated during drilling and completion operations will be hauled to the Kenai Gas Field v G&I facility for disposal/beneficial reuse depending on test results. General sequence of operations: 1. MOB Saxon Rig# 147 to well site 2. N/U 16-3/4"conductor riser. 3. Drill 12-1/4"hole to 3500' MD. Run and cmt 9-5/8" surface casing. 4. N/D conductor riser,N/U &test 11"x 5M T3-Energy BOP. 5. Drill 8-1/2"hole section to 9,679' MD. Run wireline logs. Run and cmt 5-1/2"production casing. 6. N/D BOP,N/U temp abandonment cap, RDMO. Reservoir Evaluation Plan: dee C.a5efefe_ - ett 4 1. Surface hole:No open hole logs planned. l ),h 2. Production Hole: LWD: GR+Res+Den/Neu(Triple Combo). Open hole wireline logging— Dipole sonic. ' 3. Mud loggers from surface casing point to TD. Page 7 Version 2 Sept,2014 Falls Creek#6 Drilling Procedure Hilcorp EnnsY ComP.nY 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with the below AOGCC regulations. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. • BOPs shall be tested at(2) week intervals during the drilling and completion of Falls Creek#6. Ensure to provide AOGCC 24 hrs notice prior to testing BOPs. • The initial test of BOP equipment will be to 250/3500 psi & subsequent tests of the BOP equipment will be to 250/3500 psi for 5/5 min (annular to 50% rated WP, 2500 psi on the high test for initial and subsequent tests). Confirm that these test pressures match those specified on the APD. • If the BOP is used to shut in on the well in a well control situation, we must test all BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. • All AOGCC regulations within 20 AAC 25.033 "Primary well control for drilling: drilling fluid program and drilling fluid system". • All AOGCC regulations within 20 AAC 25.035 "Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements". • Ensure AOGCC approved drilling permit is posted on the rig floor and in Co Man office. AOGCC Regulation Variance Requests: • There are no variance requests at this time. Page 8 Version 2 Sept, 2014 Falls Creek#6 Drilling Procedure Hilcorp Energy Company Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure(psi) 12-1/4" • 21-1/4"2M diverter w/16"diverter line Function Test Only • 11"x 5M T3-Energy(Model 7082)Annular BOP • 11"x 5M T3-Energy Double Ram Initial Test:250/3 o Blind ram in btm cavity (Annular 2500 psi) • Mud cross 8-1/2" • 11"x 5M T-3 Energy Single Ram • 3-1/8"5M Choke Line Subsequent Tests: • 2-1/16"x 5M Kill line 250/3500 • 3-1/8"x 2-1/16"5M Choke manifold (Annular 2500 psi) • Standpipe,floor valves,etc • Primary closing unit: Control Technologies accumulator unit, 5 station, 120 gallon(12 x 11 gal bottles). • Primary closing hydraulic pressure is provided by an electrically driven triplex pump. Emergency pressure is provided by bottled nitrogen. Required AOGCC Notifications: • Well control event(BOPS utilized to shut in the well to control influx of formation fluids). • 24 hours notice prior to spud. • 24 hours notice prior to testing BOPs. • 24 hours notice prior to casing running&cement operations. • Any other notifications required in APD. Regulatory Contact Information: AOGCC Jim Regg/AOGCC Inspector/(0): 907-793-1236/Email:jim.reggalaska.gov Guy Schwartz/Petroleum Engineer/(0): 907-793-1226/(C): 907-301-4533 /Email: guy.schwartz@alaska.gov Victoria Ferguson/Petroleum Engineer/(0): 907-793-1247/Email: Victoria.ferguson@alaska.gov_ Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov Test/Inspection notification standardization format: http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html Notification/Emergency Phone: 907-793-1236(During normal Business Hours) Notification/Emergency Phone: 907-659-2714(Outside normal Business Hours) Page 9 Version 2 Sept,2014 Falls Creek#6 Drilling Procedure Hilcorp Energy Company 9.0 R/U and Preparatory Work 9.1 Set 16" conductor at 60' below ground level. 9.2 Dig out and set impermeable cellar. 9.3 Install Seaboard slip-on 16-3/4" 3M "A" section. Ensure to orient wellhead so that tree will line up with flowline later. 9.4 Level pad and ensure enough room for layout of rig footprint and R/U. 9.5 Layout Herculite on pad to extend beyond footprint of rig. 9.6 R/U Saxon Rig# 147, spot service company shacks, spot&R/U company man&toolpusher offices. 9.7 Mud loggers are NOT required on the surface hole section, but can be R/U if deemed necessary to help select surface casing point. 9.8 After rig equipment has been spotted, R/U handi-berm containment system around footprint of rig. 9.9 Mix mud for 12-1/4" hole section. 9.10 Set test plug in wellhead prior to N/U conductor riser to ensure nothing can fall into the wellbore if it is accidentally dropped. 9.11 Install 5-1/2" liners in mud pumps. • TSM 1000 mud pumps are rated at 3633 psi (85%)/333 gpm(100%)with 5-1/2" liners. Page 10 Version 2 Sept,2014 Falls Creek#6 Drilling Procedure Hilcorp Energy Company 10.0 N/U 21-1/4" 2M Diverter System 10.1 N/U 21-1/4" Hydril MSP 2M diverter System. • N/U 16-3/4" 3M x 21-1/4" 2M DSA (Hilcorp) on 16-3/4" 3M wellhead. • N/U 21-1/4" diverter"T". • Knife gate, 16" diverter line. ' "^(j-L-1- Cc: A-A,L(L. • Ensure diverter R/U complies with AOGCC re 0.AAC.25.035(C). 10.2 Function test diverter. Ensure that the knife gate and annular are operated on the same circuit so that knife gate opens prior to annular closure. 10.3 Ensure to set up a clearly marked"warning zone" is established on each side and ahead of the vent line tip. "Warning Zone" must include: • A prohibition on vehicle parking • A prohibition on ignition sources or running equipment • A prohibition on staged equipment or materials • Restriction of traffic to essential foot or vehicle traffic only. 10.4 Set 15.375" ID wearbushing in wellhead. Page 11 Version 2 Sept, 2014 H FFalls Creek#6 Drilling Procedure Hilcorp Energy Company 10.5 Rig & Diverter Orientation on Falls Creek pad: „.,..., \ ." _ , , .. z • .,K ../ / l ' ' • CA/ /S. //O. /2/r.' EF3t HI DINT4 .,•• „ • .-- „, .6' -, , -, r- -• \ sk•-\/ '- ' - ' 9 Vi t NTROL .‘,.-.... \ 0, , ., 0 ,... ,. \::::•:. ;:.2,-,;,-,..., / / // • 0/ , , ,•-• // ',.. <<CLV 7 7' •, ••••.„ Ng"':\ . 4 .•'.-::.-•(,//,.) \ 1 i,., —:' g• •- . i 1 , 40' •7''..-../ • ,.-,.?4," • -'S. ,'" • ,'/ \ly / ./.5:->. VALVE,,,,.:, ____ ... . .. --- • ,,,...\ BUILDING . ...•-•,, ,., __----- ...../ /AC' _Olvil PRESSOR 46A' 54::.i.,-•,..., __-.4-- _ / BLDG. ;•`\ _ - - ,„ -- 1 --.77--r---'_--- ---1 I x4-. . ...•'‘. -":-:::;:.'VI _-,-,- _ Xt/ I FALL; 1 Wr N 015 ...-f. 1 ' -', .•'••••',4e.i.N ./ .,-------- ---- ---- ./ .,9 • , N•-4, ,.:..,,;.• •4.1.Z ...." _.----- „ ...-- ,„--' FALLS ' .•*. •- • r . .. ....,, ..., , • CREEK FALLS1 / -- , ;.-•. ; :,..44:. /:--44"--, ----.. / .. -, --,i-,...: . -?... , ' • -,.. .7 ... :0-- CREEK i / .4.'.. ,...... - ,. to;,, /7---- ---/ NO_ 3 <i';” ,-/... ",•1'.4#1". .... .e: ,,.'•,.(.b..-:."!• .,-''' ' ' aw- ,r-,,:k.:.-./. /, _.,./ — ' :-:-.:.' ,/*-4 ....,) //) FALLS CREEK NO. 6 ///' • ‘;'//// s' AS B 'ft ..:_. NAD27 ASP ZONE 4 FALLS / /-, N:2269464_23 .• / // CREEK i // /- E:240096.85 N0 4 „iv' /7 / LATITUDE: 60°1216.029"N .. WATER WELL . • / LON G ITU DE:151°25'43.227W , .. ''''-'-'4'•---.7..., ..- 4/ . ELEV. 248_31 NAVD88 • 1906' FSL ..., .. % ,. ..• N,_.... Page 12 Version 2 Sept. 2014 Falls Creek#6 Drilling Procedure Hilcorp Energy Company 11.0 Drill 12-1/4" Hole Section 11.1 P/U 12-1/4" directional drilling assy: • Ensure BHA components have been inspected previously. • Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. • Ensure TF offset is measured accurately and entered correctly into the MWD software. • Ensure Gyro MWD is R/U and operational. Be sure to run a UBHO sub so that wireline orientation is possible if necessary. • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. • Workstring will be 4.5" 16.6# S-135 CDS40. 11.2 12-1/4" BHA (No LWD planned in surface hole): COMPONENT DATA Allialiallirlik RemID Ga Cumulative Descrip ° nil Number tE 4, (in) (m} ''Length (tt) ME HOBS FX56M PDC 12.200 2.750 12.250 378.15 B b-518-REG 1.00 1.00 © A'SperryDnil Lobe 415-5.3 stg 8.000 5.000 121.08 OM= 28.99 29.99 .11 Stabilizer 11.500 © Non Mag Stabilizer 8.000 2.813 12.125 150.12 B 6-518'REG 6.00 35.99 KM B'DM Collar(Directional) . 8.000 3.500 147.40 8 6-518'REG 9.20 MEM © 8'TM-HOC(nuttier) 8.150 4.000 145.20 B 6-58'REG 15.77 60 96 Non Mag Flex Drill Collar _ 8.000 3.000 147.22 t 30.00 90.96 Non Mag Flex Drill Collar 8.000 3.000 147.22 B 6-5/8'REG 30.00 120.96 0 X-0 6-5/8 Reg Pin X 4-12'IF Box 8.000 2.813 150.12 B 4-1/2'1F 3.50 124.46 • 8-3/4'Non Mag Flex Drill Collar 6.750 2.750 101.71 B 4-12'IF 30.00 154.46 10 6.3/4'Non Mag Flex DNI Collar 6.750 2.750 101.71 B 4-12'IF 30.00 184.46 NM X-O 4-12'IF Pin X 4-12'CDS 40 Box 6.500 2.750 92.85 B 4.5'CDS 40 2.75 187.21 © 6 joints 4-12'COS 40 HWDP 4.500 2.500 37.47 180.00 367.21 ® X-0 4-112 CDS 40 Pin X 4-112'IF Box 6.500 2.750 92.85 B 4-12'IF 2.75 369.96 En Weatherford 6-1/4'Hyd Jar 6.250 2.250 91.01 B 4-12'IF 30.00 399.96 ® X-O 4-12"IF Pin X 4-112'CDS 40 Box 8.500 2.750 92.85 B 4.5'CDS 40 2.75 402.71 m 19 Joints 4-112 CDS 40 HW DP 4.500 2.500 37.47 570.00 972.71 Total: 972.71 BIT DATA Bk Number Nozzles :9x13 Bit Size (in) : 12250 TFA (in2) : 1.1666 Manufacturer Dun Grade In . Model Dub Grade Out .• Serial Number .• MOTOR DATA Motor Number : 2 Bend (deg) : 1.15 OD (in) :8.000 Nozzles (32nd) : 0.0 Manufacturer : Sperry Drilling Avg Diff Press . Model : SperryDrill Cumul Cir Hrs .• Serial Number _ Page 13 Version 2 Sept, 2014 Falls Creek#6 Drilling Procedure Hilcorp Energy Company 11.3 Primary Bit: 12-1/4" (311MM) QHCIGRC PRODUCT SPECIFICATIONS IADC Code 117W Total Tooth Count 67 Gage Row Tooth Count 39 Journal Angle 33° Offset(11161 6 • ,✓` Jet Nozzle Types Standard 83144 Extended 302447 Center Jet (If Center Jetted)501813 T.J.Connection 6-5/8"(API Reg.) Recommended Make-Up Torque* 2SOOOi32000 Ft•lbs. Bit Weight(Boxed) 250 Lbs.i 113 Kg.) Bit Breaker (Mat.#/Legacy#) 515353;506463 PRODUCT FEATURES . New patented Diamond***Clawl tooth bit design. • . Tungsten carbide'surf inserts in gage teeth for added gage protection. • Newly formulated,proprietary hardfacing on cutting structure and gage maximizes carbide and diamond volume for ultimate wear , - resistance. # ti • High-speed bearing designed for high rpm and high-energy applications. . Innovative mechanical pressure compensating system provides reliable pressure equalization and relief for maximum bearing and seal life. . Raised tungsten carbide inserts and proprietary hard facing provides maximum arm protection in abrasive and directional applications while minimizing drill string torque. . QuadPackff Plus Series incorporates its successful"longevity" features and patented engineered hydraulics system for optimal cleaning efficiency. . Center jet feature to prevent bit balling problems Material#622394 'Calculations based on recommendations from API and tool-joint manufacturers. C 2012 Halliburton.All rights reserved.Sales of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale. Page 14 Version 2 Sept,2014 Falls Creek#6 Drilling Procedure Hilcorp 11.4 4-1/2" Workstring &HWDP will come from Saxon. Jars will come from Weatherford. 11.5 Begin drilling out from 16" conductor at reduced flow rates to avoid broaching the conductor. 11.6 Drill 12-1/4"hole section to 3,500' MD. Confirm this setting depth with the geologist and Drilling Engineer while drilling the well. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Pump at 500 - 550 gpm. Ensure shaker screens are set up to handle this flowrate. • Utilize Inlet experience to drill through coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team. • Keep swab and surge pressures low when tripping. • Make wiper trips every 500' or every couple days unless hole conditions dictate otherwise. • Ensure shale shakers are functioning properly. Check for holes in screens on connections. • Adjust MW as necessary to maintain hole stability. • TD the hole section in a good shale btwn 3500' MD and 3550' MD. ' • Take MWD surveys every stand drilled (60' intervals). - 11.7 12-1/4" hole mud program summary: Weighting material to be used for the hole section will be barite. Additional barite will be on location to weight up the active system (1)ppg above highest anticipated MW. We will start with a simple gel +FW spud mud at 8.8 ppg. Pason PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. System Type: 8.8—9.5 ppg Pre-Hydrated Aquagel/freshwater spud mud Properties: Depths Density Viscosity Plastic Viscosity Yield Point API FL LGS 80-3500' 8.8-9.5 ' 85-150 20-40 25-45 <10 <15% System Formulation: M-1 Gel + FW spud mud Product Concentration Fresh Water 0.905 bbl M-I Gel Export 20 ppb M-I Wate As needed Soda Ash 0.5 ppb Caustic Soda 0.1 ppb Busan 1060 0.04ppb Page 15 Version 2 Sept, 2014 Falls Creek#6 Drilling Procedure Hilcorp Emu Company 11.8 At TD; pump sweeps, CBU, and pull a wiper trip back to the 16" conductor shoe. 11.9 TOH with the drilling assy, handle BHA as appropriate. 11.10 No open hole logging program planned for Falls Creek#6 surface hole. Ar /0 fV 4e- a. e 5 ez✓A. lce: ` st. d <`�� Gtc-itc /u C,o <Zc�c'c'� ./o� . e Page 16 Version 2 Sept, 2014 Falls Creek#6 Drilling Procedure Hilcorp Energy Company 12.0 Run 9-5/8" Surface Casing 12.1 R/U and pull 15.375"wearbushing. 12.2 R/U Weatherford 9-5/8" casing running equipment. • Ensure.9-5/8"BTC x CDS 40 XO on rig floor and M/U to FOSV. • R/U fill-up line to fill casing while running. • Ensure all casing has been drifted on the location prior to running. • Be sure to count the total # of joints on the location before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/vendor&model info. 12.3 P/U shoe joint,visually verify no debris inside joint. 12.4 Continue M/U&thread locking shoe track assy consisting of: • (1) Shoe joint w/float shoe bucked on (thread locked). • (1) Joint with coupling thread locked. • (1)Joint with float collar bucked on pin end &thread locked. • Install (2) centralizers on shoe joint over a stop collar. 10' from each end. • Install (1) centralizer,mid tube on thread locked joint and on FC joint. • Ensure proper operation of float equipment. 12.5 Continue running 9-5/8" surface casing • Fill casing while running using fill up line on rig floor. • Use"API Modified"thread compound. Dope pin end only w/paint brush. • M/U connections to the base of the triangle stamped on the pin end. Note M/U torque values required to achieve this position. • After making up several connections,use the torque required to M/U to base of triangle as the M/U torque and continue running string. • Install (1) centralizer every other joint to 300'. Do not run any centralizers above 300' in the event a top out job is needed. • Utilize a collar clamp until weight is sufficient to keep slips set properly. 9-5/8" BTC Estimated M/U Torque Casing OD Est Torque to Reach Triangle Base 9-5/8" 9,630 ft-lbs Page 17 Version 2 Sept, 2014 Falls Creek#6 Drilling Procedure Hilcorp Energy Company Tenaris Casing and Tubing Performance Data Choose pipe size.wall thickness and steel grade to view API connection options and performance data. Size -0 Wall 0 Grade-0 Connection 10 Unit _0 Pipe Body Data GEOMETRY • Nominal OD 9.625 in Wail Thickness 0.395 in API Drift Diameter 8.679 in Nominal Weight 40.00lbsift Nominal ID 8.835 in Alternate Drift Diameter 8.75 in Plain End Weight 38.97 bstft Nominal Cross Section 11.454 sq in PERFORMANCE Steel Grade L80 Minimum Yield 80,000 psi Minimum Ultimate 95,000 psi Body Yield Strength 916,000 lbs Internal Yield Pressure 5,750 psi Collapse Pressure 3,080 psi • Connection Data GEOMETRY Regular OD 10.625 in Threads Per Inch 5 Make-Up Thread Turns 1 PERFORMANCE Steel Grade L80 Minimum Yield 80.000 psi Minimum Ultimate 95,000 psi ;Joint Strength 947.000 lbs Internal Pressure 5,750 psi Resistance TenarisHydrii Premium Connections Print I Contact Us Ver 8.6 12.6 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 12.7 Slow in and out of slips. 12.8 P/U casing hanger joint and M/U to string. Casing hanger joint will come out to the rig with the landing joint already M/U. Position the shoe as close to TD as possible. Strap the landing joint while it is on the deck and mark the joint at(1) ft intervals to use as a reference when landing the hanger. 12.9 Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. Page 18 Version 2 Sept, 2014 Falls Creek#6 ti Drilling Procedure Hilcorp Energy Company 12.10 R/U circulating equipment and circulate the greater of 1 x casing capacity or 1 x OH volume. Elevate the hanger offseat to avoid plugging the flutes. Stage up pump slowly and monitor losses closely while circulating. 12.11 After circulating, lower string and land hanger in wellhead again. Page 19 Version 2 Sept, 2014 .. ..___..._._._._. Falls Creek#6 Drilling Procedure Hilcorp Energy Company 13.0 Cement 9-5/8" Surface Casing 13.1 Hold a pre job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud&water can be delivered to the cmt unit at acceptable rates. • How to handle cmt returns at surface. • Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. • Positions and expectations of personnel involved with the cmt operation. 13.2 Document efficiency of all possible displacement pumps prior to cement job 13.3 R/U cmt head(if not already done so). Ensure top and bottom plugs have been loaded correctly. 13.4 Pump 5 bbls 10 ppg spacer. Test surface cmt lines. 13.5 Pump remaining 35 bbls 10 ppg spacer. 13.6 Drop bottom plug. Mix and pump cmt per below recipe. 13.7 Cement volume based on annular volume+ 50% open hole excess. Job will consist of lead& tail, TOC brought to surface. Estimated Total Cement Volume: Section: Calculation: Vol (BBLS) Vol(ft3) LEAD: 80' x .129 bpf= 10.3 57.8 16" Conductor x 9-5/8" casing annulus: LEAD: (3000' — 80') x .0558 bpf x 1.5 = 244.4 1372 12-1/4" OH x 9-5/8" Casing annulus: Total LEAD: 254.7 bbl 1430 ft3 TAIL: (3500'-3000')x .0558 bpf x 1.5 = 50 282 12-1/4" OH x 9-5/8" Casing annulus: TAIL: 90 x .096 bpf = 8.7 48.8 9-5/8" Shoe track: Total TAIL: 58.7 bbl 331 ft3 Page 20 Version 2 Sept, 2014 Falls Creek#6 14Drilling Procedure Hilcorp Energy Company Cement Slurry Design: Lead Slurry (3000' MD to surface) Tail Slurry(3500'to 3000' MD) System Extended Conventional Density 12.5 lb/gal 15.2 lb/gal Yield 2.13 ft3/sk 1.25 ft3/sk Mixed 12.02 gal/sk 5.7 gal/sk Water Mixed Fluid 12.03 gal/sk 5.71 gal/sk Code Description Concentration Code Description Concentration Type1 Cement 94 lb/sk WBWOB Type1 Cement 94 lb/sk WBWOB Static Free De-Foamer 0.005 lbs/sk Static Free De-Foamer 0.005 lbs/sk CaCI Accelerator 2% bwoc CaCI Accelerator .25%bwoc Additives CD-32 Dispersant 0.4%bwoc CD-32 Dispersant 0.5%bwoc FL-52 Fluid Loss Add 0.3% bwoc FL- 2 Fluid Loss Add0.2% bwoc FP-6L De-Foamer 1 gal/100 sk FP-6L De-Foamer 1 gal/100 sk Na Extender 2% bwoc Metasillicate 13.8 Attempt to reciprocate casing during cement pumping if hole conditions allow. Keep the hanger elevated above the wellhead while working. If the hole gets "sticky", land the hanger on seat and continue with the cement job. 13.9 After pumping cement, drop top plug and displace cement with 9.5 ppg Kla-shield. 13.10 Ensure cement unit is used to displace cmt so that volume tracking is more accurate. 13.11 Displacement calculation: 3400' x .0758 bpf=257.7 bbls 13.12 Monitor returns closely while displacing cement. Adjust pump rate if necessary. If hanger flutes become plugged, open wellhead side outlet in cellar and take returns to cellar. Be prepared to pump out fluid from cellar. Have some sx of sugar available to retard setting of cement. 13.13 Do not overdisplace by more than '/2 shoe track volume. Total volume in shoe track is 8.7 bbls. 13.14 Be prepared for cement returns to surface. If cmt returns are not observed to surface, be prepared to run a temp log btwn 6— 18 hours after CIP. 13.15 Be prepared with small OD top out tubing in the event a top out job is required. The AOGCC will require us to run steel pipe through the hanger flutes. The ID of the flutes is 1.5". Page 21 Version 2 Sept, 2014 Falls Creek#6 Drilling Procedure Hilcorp Emmy Company 13.16 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold, pressure up string to final circulating pressure and hold until cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating pressure if pressure must be held. 13.17 R/D cement equipment. Flush out wellhead with FW. 13.18 Back out and L/D landing joint. Flush out wellhead with FW. 13.19 M/U pack-off running tool and pack-off to bottom of Landing joint. Set casing hanger packoff. Run in lock downs and inject plastic packing element. 13.20 Lay down landing joint and pack-off running tool. Ensure to report the following on wellez: • Pre flush type,volume(bbls)&weight(ppg) • Cement slurry type, lead or tail, volume&weight • Pump rate while mixing,bpm,note any shutdown during mixing operations with a duration a. Pump rate while displacing,note whether displacement by pump truck or mud pumps,weight&type of displacing fluid b. Note if casing is reciprocated or rotated during the job c. Calculated volume of displacement, actual displacement volume,whether plug bumped&bump pressure, do floats hold d. Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure e. Note if pre flush or cement returns at surface&volume f. Note time cement in place g. Note calculated top of cement h. Add any comments which would describe the success or problems during the cement job Send final "As-Run" casing tally & casing and cement report to lkeller@hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. Page 22 Version 2 Sept,2014 Falls Creek#6 111 Drilling Procedure Hilcorp Energy Company 14.0 BOP N/U and Test 14.1 N/D the conductor flow riser. 14.2 N/U Seaboard multi-bowl wellhead assy. Install packoff 9-5/8" P-seals. Test to 3000 psi. 14.3 N/U 11"x 5M T3-Energy BOP as follows: • BOP configuration from Top down: 11"x 5M T3-Energy annular BOP/11"x 5M T3-Energy Model 6011i double ram/11"x 5M mud cross/11"x 5M T3-Energy Model 6011i single ram • Double ram should be dressed with 2-7/8 x 5" VBRs in top cavity, blind ram in btm cavity. • Single ram should be dressed with 2-7/8 x 5"VBRs • N/U bell nipple, install flowline. • Install (2) manual valves &a check valve on kill side of mud cross. • Install (1) manual valve on choke side of mud cross. Install an HCR outside of the manual valve. 14.4 Run 4-1/2"BOP test assy, land out test plug (if not installed previously). • Test BOP to 250/3500 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. • Ensure to leave "B" section side outlet valves open during BOP testing so pressure does not build up beneath the test plug. 14.5 R/D BOP test assy. 14.6 Dump and clean mud pits, send spud mud to G&I pad for injection. 14.7 Mix 9.5 ppg Ma-Shield mud system. 14.8 R/U mud loggers for production hole section. 14.9 Set 10"ID wearbushing in wellhead. 14.10 Rack back as much 4-1/2" DP in derrick as possible to be used while drilling the hole section. 14.11 Keep 5-1/2" liners in mud pumps. Page 23 Version 2 Sept, 2014 Falls Creek*6 Drilling Procedure Hilcorp Enemy Comp's). 15.0 Drill 8-1/2" Hole Section 15.1 P/U 8-1/2" directional BHA. 15.2 Ensure BHA components have been inspected previously. 15.3 Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. 15.4 TF offset is measured accurately and entered correctly into the MWD software. 15.5 Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. 15.6 Workstring will be 4.5" 16.6# S-135 CDS40. Page 24 Version 2 Sept, 2014 Falls Creek#6 iti Drilling Procedure Hilcorp Energy Company 15.7 8-1/2" BHA (Includes GR+Res+Den/Neu LWD components): COMPONENT DATA jillrmw 00 ID Gauge Weight Length Cumulative Item,'. 9 9 Top 9 # Description Serial Number Connection .i (in) (in) (in) (Ibpf) (ft) Length (ft) Ell HDBS-FX85D 8.400 2.500 8.500 172.13 P 4-112'REG 1.00 1.00 © i SperryDrifl Lobe 718-6.0 stg 7.000 4.952 93.13 B 4-1/2"IF 27.38 28.38 - Stabilizer -__ 7.750 _--- © Non Mag Float Sub 6.750 2.750 131 71 B 4-112"IF 3.00 MEE ® Integral Blade Stabilizer(NM) 6.750 I= 8.375 130 77 B 4-':2"IF 500 36.38 E. 6 34"DM(Directional) 6.750 3.125 103 40 B 4-112"iF 9.2C 6 6 314'DGR(Gamma) 6.750EMI_ 97.80 B 4-1/2"IF 4.55 50.14 © 5 314"EWR-P4 (Resistivity) 6.750 2.000 104-30 B 4-112"IF 12."C 62.24 ICI 8 314'HCIM (Processor; . 6.750 1 920 101.70 B 4-112'IF 4.97 67.21 9 6 3/4"ALD Collar 175C 30KS1 6.750 1 92C 8.250 104.30 P NC 50 14.54 81.75 - Stabilizer -__ 8.250 _--ISE= ® 6 314'CTN Collar 175C 30KSI 6.750 1.905 102.30 B NC 50 11.84 93.59 Ell 6 314"TM-HOC(Pulser) 6900 3.250 133.60 B 4-':2"IF 15.59 139.18 ® 6-314"Non Mag Flex Drill Collar 6.750 2.813 100.77 B 4-1/2"IF 30.00 139.18 MIN 6.314"Non Mag Flex Drill Collar 6.750 2.813 _ 100.77 B 4-112'IF 30.00 159.18 ® X-0 4-1/2"CDS 40 Box X 4-1/2"IF Pin 8.500 2.750 92.85 B 4.5'CDS 40 2.75 IIIIM ® 6 Joints 4-112"COS 40 HWDP 4.500 2.500 37 47 180.00 351.93 ® X-0 4-112'IF Box X 4-1/2"CDS 40 Pin 6.500 2.750 92.85 B 4-112'IF 2.75 354.68 ® Weatherford 6-1?4"Jars 6.250 2.250 91.01 B 4-112-IF 30.00 384.68 En X-O 4-1.12'IF Pin X 4-1'2"CDS 40 Box 6.500 2.750 92.85 B 4.5"CDS 40 2.75 387.43 ® 19 Joints 4-112'CDS 40 HWDP 4.500 2.500 37.47 570.00 957.43 Total: 957.43 BIT DATA Bit Number Nozzles :5x13 Bit Size (in) : 8.500 TFA (in2) :0.6481 Manufacturer Dull Grade In • Model Dull Grade Out Serial Number • Page 25 Version 2 Sept, 2014 Falls Creek#6 Drilling Procedure Hilcorp Energy Company 15.8 Primary Bit: 8-1/2" (216mm) MM65M PRODUCT SPECIFICATIONS Cutter Type SelectCutter IADC Code M324 Body Type MATRIX Total Cutter Count 41 Cutter Distribution 13mm 16mm Amy Face 1 29 i ,� Gauge 5 0 . Up Drill 6 0 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 of Replaceable Ports(Size) 0 Junk Slot Area(sq in) 14.81 9898,§ Normalized Face Volume 42.1340 API Connection 4-112 REG.PIN Recommended Make-Up Torques 12.461—17,766 Ft*lbs. "`+"+ , s Nominal Dimensions** Make-Up Face to Nose 10.73 in-273 mm `* Gauge Length 2.5 in-64 RIM Sleeve Length 0 in-0 mm Shank Diameter 6 in-152 mm Break Out Plate(Mat.#.'Legacy#) 181954/44040 Approximate Shipping Weight 160Lbs.-73Kg. SPECIAL FEATURES 1132"Relieved Gage,Combination Backream/Up-Drill Cutters. Secondary Cutting Element-"R"Feature,TSP Gage Material#803275 'Bit specific recornm ended make-up torque is a function of the bit ID.and actual bit sub D_t)_utilized as specified in API RP7G Section A_8.2. "Designdirncueions are nominal and may vary slightly on manufactured product.Halliburton Drill Bits and Services models are continuously reviewed and refined. Product specifications may change without notice. C 2013 Halliburton.All rights reserved.Sales of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale. Page 26 Version 2 Sept, 2014 Falls Creek#6 14Drilling Procedure Hilcorp Energy Company 15.9 8-1/2"hole section mud program summary: Weighting material to be used for the hole section will be salt and calcium carbonate. Additional calcium carbonate will be on location to weight up the active system (1) ppg above highest anticipated MW. NOTE: Only use the "Black Products" & corrosion inhibitors if absolutely necessary. These products can leave behind a damaging skin that affects productivity of the well. Pason PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. System Type: 9.5 ppg Kla-Shield fresh water based drilling fluid with 6%KC1. Properties: Depths Density Plastic Viscosity Yield Point Chlorides API FL pH 3500'-9,679',. 9.5 ' 10-20 15-25 60,000—70,000 <8 9.0- 10 System Formulation: M-1 Swaco Kla-Shield with 6% KCI Product Concentration/Function Water Base Fluid Busan 1060 0.4 ppb Biocide Soda Ash 0.25 ppb PH/Hardness Control Flowzan 1.0 ppb Viscosifier/Rheology KCL 21.8 ppb weight/inhibition NaCI Salt 20.Oppb weight/inhibition Poly Pac Sup UL 0.75 ppb API Fluid Loss EMI-2009 2-3%v/v Clay/Shale inhibitor Safe-Carb 40 If needed for weight increase over Conqor 404 9.Oppg Asphasol Supreme Corrosion Mitigation Sack Black 4ppb Shale/Coal Stabilizer 3ppb-Gilsonite Shale/Coal Stabilizer 15.10 TIH w/ 8-1/2" directional assy to TOC. Shallow test MWD and LWD on trip in. Note depth TOC tagged on AM report. 15.11 R/U and test casing to 2900 psi/30 min. Ensure to record volume/pressure and plot on FIT graph. AOGCC reg is 50% of burst= 5750/2 = 2875-2900 psi 15.12 Drill out shoe track and 20' of new formation. Page 27 Version 2 Sept, 2014 Falls Creek#6 Drilling Procedure Hilcorp Energy Company 15.13 CBU and condition mud for FIT. 15.14 Conduct FIT to 12 ppg EMW. Note: Offset field test data predicts frac gradient at the 9-5/8" shoe to be btwn 17- 18 ppg EMW. A 12 ppg FIT results in a 2.5 ppg kick margin while drilling with the planned MW of 9.5 ppg• 15.15 Drill 8-1/2" hole section to 9,679' MD / 8,767' TVD. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Pump at 400 - 450 gpm. Ensure shaker screens are set up to handle this flowrate. • Utilize inlet experience to drill through coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team, try to avoid sliding through coal seams. Work through coal seams once drilled. • Keep swab and surge pressures low when tripping. • Make wiper trips every 500' or every couple days unless hole conditions dictate otherwise. • • Ensure shale shakers are functioning properly. Check for holes in screens on connections. • Adjust MW as necessary to maintain hole stability. Keep HTHP fluid loss < 10. • Take MWD surveys every other stand drld. Surveys can be taken more frequently if deemed • necessary. • Mud loggers: Take samples every 30 ft, with 20 ft samples in zones of interest. Two sets of cuttings required, gas chromatograph,pixler plots. 15.16 At TD; pump sweeps, CBU, and pull a wiper trip back to the 9-5/8" shoe. 15.17 TOH with the drilling assy, stand back BHA if possible. Drop a drift on the last trip out of the hole in preparation for running the liner. 15.18 R/U and run OH wireline logs consisting of: • Dipole Sonic 15.19 Monitor the well at all times on the trip tank while logging. / 15.20 After logging objectives accomplished, pick up a wiper trip BHA and make another run to TD. Circ B/U at TD and TOH. Rack back DP, handle BHA as appropriate. Page 28 Version 2 Sept, 2014 Falls Creek#6 Drilling Procedure Hilcorp Energy Company 16.0 Run 5-1/2" Production Casing 16.1. R/U 5-1/2"casing running equipment. • Ensure 5-1/2"DWC/C x CDS 40 crossover on rig floor and M/U to FOSV. • R/U fill up line to fill casing while running. • Ensure to R/U Tesco or Weatherford CRT so that string can be rotated if necessary while running. • Ensure all casing has been drifted on the deck prior to running. • Be sure to count the total#of joints on the deck before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/vendor&model info. 16.2. P/U shoe joint, visually verify no debris inside joint. 16.3. Continue M/U&thread locking shoe track assy consisting of: • (1) Shoe joint w/shoe bucked on&threadlocked(coupling also thread locked). Install (2) solid body centralizers on shoe joint prior to bucking on float shoe. The centralizers should be held in place 10' from each end via stop rings on either side. • (1) Thread locked joint(coupling thread locked). Install one coupling on thread locked joint and leave it free floating on the joint. • (1) Joint with float collar bucked on pin end &threadlocked (coupling also thread locked). Install(1) solid body centralizer on float collar joint prior to bucking on float collar. • Ensure proper operation of float shoe and float collar prior to running in the hole. 16.4. Continue running 5-1/2"prod casing. • Fill casing while running using fill up line on rig floor. • Use "Best 0 Life 2000"thread compound. Dope pin end only w/paint brush. • Install solid body centralizers on every joint to 5,400 MD. Every other joint to 3800'. None above 3800'. Leave the centralizers free floating. • Utilize a collar clamp until weight is sufficient to keep slips set properly. 5-1/2" CDC M/U torques Casing OD Minimum Maximum Yield Torque 5.5" 8,500 ft-lbs 10,500 ft-lbs 13,000 ft-lbs Page 29 Version 2 Sept, 2014 Falls Creek#6 II Drilling Procedure Hilcorp Energy Company coU. S. Steel Tubular Products 5.5 1710.304 P110 HC USS-CDC TM 7.'"2l14''.152 rit .JZI rLj^43`LJy.1°.1 e l '.' d'1..'4# +_'f L.. '{g MECHANICAL.PROPERTIES Pipe U6$COC" Minimum Yield Strength 110.000 psi Maximum Yield Strength 140,000 - pet Minimum Tensile Strength 125,000 - psi DIMENSIONS Piper U66CDC" Outside Diameter 5.500 6_050 in. Wall Thickness 0,304 - in Inside Diameter 4.892 4.892 in. Standard Drift 4,767 4.767 in. Alternate Drift .. - ,n. Coupling Length -- 9 250 in. Nominal Leiter Weight,T&C 17.00 .• lbslft Plain End Weight 1689 -- lbs/ft SECTION AREA Pip* U68•COcni Critacal Area - 4.962 sq.in .feint Efficiency - 100.0 Sb PERFORMANCE Minimum Co:ap.o Pressure 8,730 8,730 tai External Pressure - 6,984 psi Minimum Internal Yield Pressure 10.540 10,600 psi Minimum Pipe Body Yield Strength 545 - 1000 Itis Joint Strength -- 568.030 1000 lbs Compression Rating - 340,800 lhs Reference Length .. '22,275 ft Maximum Uniaxial Bound Paling - 57.2 63000 tt Make-tip Lo: .- 4,63 in. Minimum Make-Up Torque -- 8,500 ft-be Meximurri Make•Up Torque -- 10.500 ft-bs Connection Yield Torque -- 13,000 6-be Verification of connection shoulder regcrred rwolcal shoukder range 16.5. M/U casing hanger joint to string. Casing hanger joint will come out to the rig with the landing joint already M/U. Position the shoe approx 10—20' above TD. Strap the landing joint while it is on the deck and mark the joint at(1) ft intervals to use as a reference when landing the hanger. Page 30 Version 2 Sept,2014 Falls Creek#6 ti Drilling Procedure Hilcorp Enemy Company 16.6. Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. 16.7. R/U circulating equipment and circulate the greater of 1 x casing capacity or 1 x OH volume. Elevate the hanger offseat(slightly) to avoid plugging the flutes. Stage up pump slowly and monitor losses closely while circulating. 16.8. After circulating, lower string and land hanger in wellhead again. Page 31 Version 2 Sept, 2014 Falls Creek#6 Drilling Procedure Hilcorp Energy Company 17.0 Cement 5-1/2" Production Casing 17.1. Hold a pre job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud& water can be delivered to the cmt unit at acceptable rates. • How to handle cmt returns at surface, regardless of how unlikely it is that this should occur. • Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. • Positions and expectations of personnel involved with the cmt operation. • Document efficiency of all possible displacement pumps prior to cement job. 17.2. Attempt to reciprocate the casing during cmt operations. 17.3. Pump 5 bbls 10 ppg SealBond spacer. 17.4. Test surface cmt lines to 4500 psi. 17.5. Pump remaining 15 bbls 12 ppg SealBond spacer. 17.6. Mix and pump lead and tail cmt per below recipe. Ensure cmt is pumped at designed weight. Job is designed to pump 30%OH excess. Section: Calculation: BLS) Vol (ft3) (B9-5/8" x 5-1/2" Overlap(Lead): 500' x 0.046 = 23 129 8-1/2" OH x 5-1/2" Liner(Lead): (6,350—3,500') x 0.0408 x 1.3 = 151.1 848.4 8-1/2" OH x 5-1/2"Liner(Tail): (9,679' —6,350')x 0.0408 x1.3 = 176.6 955.1 Shoe Track(Tail): 90' x 0.023 = 2.1 11.8 Total Volume(Lead): 174.1 bbls 977.6 ft3 Total Volume (Tail): 178.7 bbls 966.9 ft3 Page 32 Version 2 Sept, 2014 Falls Creek#6 11 Drilling Procedure Hilcorp Energy Company Lead Slurry (6350' to 3500') Tail Slurry (9558' to 6350' MD) System Extended Conventional Density 13.5 lb/gal 15.2 lb/gal Yield 1.82 ft3/sk 1.25 ft3/sk Mixed Water 9.21 gal/sk 5.7 gal/sk Mixed Fluid 9.22 gal/sk 5.71 gal/sk Code Description Concentration Code Description Concentration Class G Cement 94 Ib/sk Type1 Cement 94 lb/sk WBWOB WBWOB BA-90 Low den. additive 10% bwoc Static Free De-Foamer 0.005 lbs/sk BA-56 Gas Migration 2.5% bwoc R-3 Retarder 0.9% bwoc CD-32 Dispersant 0.4% bwoc CD-32 Dispersant 0.6% bwoc Additives Free water ASA-301 control 0.1% bwoc FP-6L De-Foamer 1 gal/100 sk Bonding FP-6L De-Foamer 1 gal/100 sk BA-10A 1% bwoc agent Metasillicate Extender 0.5% bwoc Metaa sla illicate Extender 0.5% bwoc Static Free De-Foamer 0.005 lbs/sk 17.7. Drop DP dart and displace with 6% KC1. 9400' x .023 = 216.2 bbls 17.8. Do not overdisplace by more than 1/2 shoe track. Shoe track volume is 1.7 bbls. 17.9. Bleed pressure to zero to check float equipment. 17.10. Pressure up again to 3500 psi and hold for 30 min to test production bore. Page 33 Version 2 Sept,2014 Falls Creek#6 ii Drilling Procedure Hilcorp EnorEY Company Ensure to report the following on wellez: • Pre flush type,volume(bbls)&weight(ppg) • Cement slurry type, lead or tail,volume&weight • Pump rate while mixing,bpm,note any shutdown during mixing operations with a duration i. Pump rate while displacing,note whether displacement by pump truck or mud pumps,weight&type of displacing fluid j. Note if casing is reciprocated or rotated during the job k. Calculated volume of displacement, actual displacement volume, whether plug bumped&bump pressure, do floats hold 1. Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure m. Note if pre flush or cement returns at surface&volume n. Note time cement in place o. Note calculated top of cement p. Add any comments which would describe the success or problems during the cement job Send final "As-Run" casing tally & casing and cement report to lkeller@hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. Page 34 Version 2 Sept, 2014 Falls Creek#6 Drilling Procedure Hilcorp Energy Comp.ny 18.0 RDMO 18.1 Install back pressure valve in hanger neck. N/D BOP. 18.2 Install &test production tree. 18.3 RDMO Saxon rig#147 18.4 After rig has departed, pull BPV and run CBL to determine TOC behind 5-1/2"production casing. Send the CBL to the AOGCC for review. 19.0 Perf and Frac 19.1 A separate sundry will be submitted to the AOGCC that will cover the below operations: • R/U workover rig • Run production tubing/pkr/ CIM & SCSSV. • Perforating and flowback. • And hydraulic fracturing or other stimulation that may be necessary to produce the well commercially. Page 35 Version 2 Sept, 2014 Falls Creek#6 ii Drilling Procedure Hilcorp Energy Company 20.0 BOP Schematic r— P'1 it til lil Ili rat IMINIMMOM 1. I s r el Saxon Rlg 147 r 11"5M T-3 Energy BOP nil aiIi'us 'Tirg 1 r -Enorn, Modc16U11i — _ le . . .1---1 ..„,,,, .. .... : fp. Manual h;ta.rIr.l '-----1.11-4L-----' p.1,-r L CI 11.85' Valve V•� r ;., ,e NGN 104...4.1.71.s.:.:4•••cli li 0.44;./....411,I ii if il, ikr.i474.p, .14;:f 0 Choke iJ11I !1 ftiF ! ti "' i1-Ii1-111.1#!1#1 r l''�� .-Energy Model 6911i = _ 500, 7 T Grade Love` - Spacer spool , 95, 11 SM X 11 5M l fel rr f fli v ar Ir Seaboard-MBS system ■;lam —I r+ o#} i;-i. 16 ;3MX115M ■ MINNI -, i a. 11 -4 I kil l;�ii a lia j• 4 101 .16 Page 36 Version 2 Sept,2014 Falls Creek#6 Drilling Procedure Hilcorp Energy Company 21.0 Wellhead Schematic Ninilchik Unit New drill system-Seaboard Saxon Rig 147 16 x95/8 x51/2 7 Miler AAP1 �8�/ IN UM IE i -Rill. Tubing head,Seaboard-S8, 11 5M X 7 1/16 5M, I lift E. w/22-2 1/16 5MP seal bottom 0 "�/' IM L • e °JOi I I 11. .ra Gild 1Stging _ 0-1HH -- III 11J I1, • Casing spool,Seaboard-S8, r 16 3/4 3M X 11 5M, '� �'�; w/2-2 1/16 5M SSO, I '{C(. * 9 5/8 P seal bottom ; r.7 a; a lisgeose - Starting head,Seaboard, 16%3M X16"SOW BTM, 1 1 w/2-21/165MSSO ® - 0,, '411 - 15 - 16" 9 5/8" 5Y=„ Page 37 Version 2 Sept, 2014 Falls Creek#6 Drilling Procedure Hilcorp Energy Company 22.0 Days Vs Depth Days Vs Depth 0 -Falls Creek#6 -Falls Creek#S 2000 9000 t 8 v 6000 a m \\NI&000 10000 12000 - 0 5 10 15 20 25 30 35 40 Days Page 38 Version 2 Sept,2014 Falls Creek#6 Drilling Procedure Hilcorp Energy Company 23.0 Formation Tops ANTICIPATED FORMATION TOPS&GEOHAZARDS EXPECTED Intersection Points TOP TOP NAME FLUID MD(FT) TVD(FTJ TVDSS(FT) Est.Pressure X Y +I- r -AY ., Beluga 135 Pos Gas 5461 4,906 -4.716 2110 r ..,. ,w;... .. Tyonek GAS 5748 5,159 -4.969 2218 r T-8 Tight Gas 6566 5,882 -5,692 2529 r T-10 Tight Gas 6885 6,164 -5,974 2651 r T-50 GAS 8229 7,448 -7,258 3203 T-60 GAS 8463 7,671 -7,481 r 3299 238836 2272181 T-65 GAS 8886 8.075 -7,885 r 3472 Total Depth 9528 8,690 -8.500 r 3737 r 238534 r 2272904 =Primary Objective =Secondary Objective TARGET RADIUS 100 FT Page 39 Version 2 Sept, 2014 Falls Creek#6 11 Drilling Procedure Hilcor 24.0 Anticipated Drilling Hazards 12-1/4" Hole Section: Lost Circulation: / Ensure adequate amounts of LCM are available. Safe-carb 10, 20, 40, 250, & 750. Ensure G-seal, Pecan nut plug, and Mix II are also available for more severe lost returns incidents. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of Safe-carb 10 & 20 to the active system at 1 -2 ppb. Hole Cleaning: Maintain rheology w/gel and gel extender. Sweep hole with gel or flowzan sweeps as necessary. Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. Maintain YP btwn 25 -45 to optimize hole cleaning and control ECD. Wellbore stability: Lithology through this zone is a composite of pebble conglomerate and sand in the upper intervals with intermittent clay matrix. Carbonaceous material and coal may be noted. Gravel sizes that are larger than normal can cause hole-cleaning problems. If encountered, be prepared to increase the viscosity. Excessive quantities of gravel and sand may indicate wellbore instability. Increase properties up to a YP of-50 --60 lbs/100ft2 to combat this issue. Maintain low flow rates for the intial 200' of drilling to reduce the likelihood of washing out the conductor shoe. / To help insure good cement to surface after running the casing, condition the mud to a YP of 25 - 30 prior to cement operations. Do not lower the YP beyond 25 to avoid trouble with sands that may be found on this well. Have Desco DF, SAPP, and water on hand to ensure the desired rheologies can be achieved. H2S: H2S is not present in this hole section. / No abnormal pressures or temperatures are present in this hole section. Page 40 Version 2 Sept, 2014 Falls Creek#6 11 Drilling Procedure Hilcorp Enemy Company 8-1/2" Hole Section: Lost Circulation: Ensure adequate amounts of LCM are available. Safe-carb 10, 20, 40, 250, & 750. Ensure G-seal, Pecan nut plug, and Mix II are also available for more severe lost returns incidents. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of Safe-carb 10 & 20 to the active system at 1 —2 ppb. Hole Cleaning: Maintain rheology w/flowzan. Sweep hole w/20 bbls hi-vis pills as necessary. Optimize solids control equipment to maintain density and minimize sand content. Maintain YP btwn 20 - 30 to optimize hole cleaning and control ECD. Wellbore stability: Maintain 1ppb total of PolyPac Supreme UL to maintain a thin/strong wall cake and keep HTHP filtrate below 9 ml/30 min. Maintain MW as necessary using additions of Barite. Maintain 6 ppb EMI-2009 for shale/clay inhibition. Maintain 4 ppb Asphasol Supreme & 3 ppb Sack Black for Shale/Coal • stabilizer. Maintain 6% KC1 in system for shale inhibition. Coal Drilling: The following lessons were learned from extensive experience drilling coal seams in Cook Inlet. The need for good planning and drilling practices is also emphasized as a key component for success. • Keep the drill pipe in tension to prevent a whipping effect which can disturb coal sections. • Use asphalt-type additives to further stabilize coal seams (Asphasol Supreme, Sack Black). • Increase fluid density as required to control a"running coal". • Emphasize good hole cleaning through hydraulics, ROP and system rheology. In the event that sloughing coal is encountered, consider spotting a 30 ppb Asphasol Supreme pill across the coal seam. The pill can be safely "squeezed" into the coal by closing the bag and applying pressure not to exceed the total annular pressure loss. H2S: H2S is not present in this hole section. No abnormal temperatures are present in this hole section. Page 41 Version 2 Sept, 2014 Falls Creek#6 II Drilling Procedure Hilcorp Energy Company 25.0 Saxon Rig 147 Layout 123'-7" I 36'-0" 55-6" 30'-0" 1=1 PRE-MIX TANK!TOTAL VOL 396 BOLSI II Ili `wl -'-`� 'illi IININIIINIIII I, i r ilii 1.IA41Al:IAllllllitl 11 td POMP t' I ' 1. ,w.r Gr ,w Ill f�lN!ii II11111 'i ;M r i - o *111111111111111.1111.11- !`' I A AI IpUNIrI1 I ION . iii SUJ ARI cl II I II i ay.! I�� ' I !• INIII MNM NNI 11 MUD Pump If 1 _ IiIminir i ;r s. r - . _ I. s�eFaa o>; >„iQ !Alli 1 ilia• If. .,,. I'I ►i vrni.�� ----- -111)...-,0"---:- as ' I1 �i,11N1mMINI 11111111111f111111f1111111111111111111111111111111111111[1111111111111111IIIIIIIIIIIIIIEIIIIIIIIIIIII IIIIIIIIIIII1111N11N111N1111111 P-+IUNNNNI�1�I11111111111I1111UIBllllll111_ �II11111I11111111111111111IIf11Nlllll111ry111 IIIIIIIIIII1111I IIIIIIIIIIII1lIIIIIIIIIIII1111IIIIIIIIIII1IIIIII11l11111111I1111111I111"In1uuiuull111111ii1iill�M�IIpIN.L__IILIN,III�IIMMI11111N11-� 1111-_ MIMI"'All 111111111I11111111IIIGI1111l1111111111f111111161i11iNi Falls Creek#6 Drilling Procedure Hilcorp Energy Company 26.0 FIT Procedure Formation Integrity Test (FIT) and Leak-Off Test (LOT) Procedures Procedure for FIT: 1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe). 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout .reventer(ram or annular). ) 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1-minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre-determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Page 43 Version 2 Sept, 2014 ii Falls Creek#6 Drilling Procedure Hilcorp Energy Company 27.0 Choke Manifold Schematic 1 1 I a; ' 1 a . $ - —1 r -.a, (1 t r ejp....,,,,.4, ;.:, . :II.11110 1 I . t gimp II it 1......71,5. 1 I Is: -A : - II mom •••••• 6 t.-) -,..-,- $3, , 1111.1.11i7 43 . '.71 a i ,OPPrt I, .. .. .i •1 1r11,- ._ Illi 101.1r7i I 1 P , ; k•) •,... .:3,Ar- ,,,,,-"c. 1 P . um. Al" r ".f. , 7;4,, ! ! ! :1 ,.:10 0. "" djill rik r, 1I*X:A! Fri% P g1111111allPI I . w.1101, -- _ t--'IV" -c- .:,:;.'::,T1,.. 7. ,..../......-.. 4 - ....,/': e ,."1:' ' 4,,* -;:•z:-. , e ..4 - iiik • 2 al1111111111111111 8 : •••,.. II -11. NI 0 ) 11. 6 .Ault ,,, ,.,”., .• e. P all1.111111111111 11IIIIIIIIIIIIIIII e e o 0-si p 14 1 111111.111 ---Nippw t lib 1 r-rs,i''.,,.,, :II; :1 .-N,ii.',::,•. :I ......w/, mg '11111111 iki l'IL'Z'.. 'I 31'I • ' i1• mil . 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NJ ouili Page 44 Version 2 Sept, 2014 Falls Creek#6 Drilling Procedure Hilcorp Energy Company 28.0 Casing Design Information Calculation&Casing Design Factors DATE:9124/2014 WELL:Falls Creek#6 DESIGN BY:Luke Keller Design Criteria: Hole Size 12-1/4" Mud Density: 8.8 ppg Hole Size 8-1/2" Mud Density: 9.5 ppg • Hole Size Mud Density: Drilling Mode MASP: 2750 psi(see attached MASP determination&calculation) MASP: Production Mode / MASP: 2893 psi(see attached MASP determination&calculation) Collapse Calculation: Section Calculation 1 Normal gradient external stress(0.494 psi/ft)and the casing evacuated for the internal stress Casing Section Calculation/Specification 1 2 3 4 Casing OD 9-518' 5-1/2- Top(MD) 0 0 Top(TVD) 0 0 Bottom(MD) 3,500 9.679 Bottom(TVD) 3,289 8,767 Length 3.500 9.679 Weight(ppf) 40 17 Grade L-80 P-110 Connection BTC CDC Weight wlo Bouyancy Factor(lbs) 140.000 164,543 Tension at Top of Section(lbs) 140,000 164.543 Min strength Tension(1000 lbs) 916 545 Worst Case Safety Factor(Tension) 6.54 3.31 Collapse Pressure at bottom(Psi) 1.625 4,331 Collapse Resistance wlo tension(Psi) 3.090 8,730 Worst Case Safety Factor(Collapse) 1.90 2.02 MASP(psi) 2.750 2,893 Minimum Yield(psi) 5.750 10.600 Worst case safety factor(Burst) 2.09 3.66 Page 45 Version 2 Sept, 2014 • Falls Creek#6 11 Drilling Procedure Hilcorp Energy Company 29.0 8-1/2" Hole Section MASP IIMaximum Anticipated Surface Pressure Calculation tiiicorp 8-1/2"Hole Section ..,---•• Falls Creek#6 Ninilchik Unit MD TVD Planned Top: 3500 3289 Planned TD: 9679 8767 Anticipated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG Grad Beluga 135 4,906 2110 Pos Gas 83 0.430 Tyonek 5,159 2218 Pos Gas 8.3 0.430 T-8 5,882 2529 GAS 8.3 0.430 T-10 6,164 2651 Tight Gas 8.3 0.430 T-50 7,448 3203 Tight Gas 8.3 0.430 T-60 7,671 3299 GAS 8.3 0.430 T-65 8,075 3472 GAS 8.3 0.430 TD 8,767 3770 ??? 8.3 0.430 Offset Well Mud Densities Well MW range Top(TVD) Bottom(TVD) Date Falls Creek#1 11.6-13.1 3,500 10,000 1960 Falls Creek#2 10.5-11 3,500 6,300 1966 Falls Creek#3 9.4-9.5 3,500 8,400 2003 Falls Creek#4 9-9.5 3,500 6,000 2004 Falls Creek#5 9.5-9.7 3,520 9,715 2014 Corea Creek#1 9.5-10.9 3,500 9,000 1996 Frances#1 9.5-9.8 3,500 10,000 2013 Assumptions: 1. Fracture gradient at shoe is estimated at 0.936 psi/ft based on field test data. 2. Maximum planned mud density for the 8-1/2"hole section is 9.5 ppg. 3. Calculations assume"Unknown"reservoir contains 100%gas worst case). 4. Calculations assume full evacuation of wellbore to gas Fracture Pressure at 9-5/8"shoe considering a full column of gas from shoe to surface: 3289(ft)x 0.936(psi/ft)= 3079 psi 3079(psi)-[0.1(psi/ft)'3289(ft)j=1 2750 psi MASP from pore pressure(unknown gas sand at TO,at 8.4 ppg,encountered while drilling) 8,767(ft)x 0.43(psi/ft)= 3770 psi 3770(psi)-0.1(psi/ft)'8,767(ft) 2893 psi Page 46 Version 2 Sept, 2014 Palls Creek#6 Drilling Procedure Hilcorp Energy Company 30.0 Spider Plot (NAD 27) (Governmental Sections) ADL384318 � , x4� ,,'fin,4�� 1 s,`.' ACL.21,,,..314r.D.Ad,. ADL384314 SOO2N012W <`' I SO02N013VV �..,. ...... Falls Creek 6 BHL: .-_.. ,., • • ADL389737 ADL389737 m r9•>q PM•,ae _. .17r x: FRANCES - f-1L _ NINILCHIK2. Tract:taxa ,_ AM y 2.. Falls 1 g Fails Creek , r �!y.��,y� CreekPA GTPH�C, F. T.: iCi.> i14] M FALL CRY, ADLQ00590 a- l SOO1 NO13W SOO1 N012W ,a. ..•- ra << t � 1 ggw�yy,�� K Pr,xe- INIL yfgt^� E P, Pn�e`'t;., JJ Tra:t B• .L. �,,� r,�cam Pr.ak P Legend PrNarr '" _ � rt� _ - F • =atn Creek a SHL 3,r { v..: —�. err al=Traci r! .,. 1 Flkvxe �r�_ FaCs Creek 6 TPH y �' ...... ....._.. --Ell------- t .-- .. -4- .0Ps Creek C SHL E J J r — a Other S.Jr ce Hobs Loci _ �... -• a ..rte Minces t• FRANCES f Older Bottum Nok Locator 4643 313E�eMPfla a 'it 'i TP�ry ate 01�HLi/SCC. 7 Well pains FRANCES WE Par:els J PG1 13-IL GS arty Gas Partclpalln9 Area acci�.,c t 5:. fii4]9, rJ Of any Gas LJn1M Boundary 2 Tract 3 Tr :(.1s 4oII3a97X +c 'o2s?a ' +090363 II Ninilchik Unit Falls Creek 6 Feet 2.003 AasMa Stale Plane Zine 4.taAr1,27 A I14l wp ANAL 1.1 1 Moo Dalen.2II:014 Page 47 Version 2 Sept,2014 Falls Creek#6 ti Drilling Procedure Hilcorp Energy Company 31.0 Surface Plat (As Built) (NAD 27) P ' i. // i s SECTION 4i, FTA$ 81211$ SM," AX f / i GOVTLOT 3&N 1/2 sr 1/4 // £xMONO NOM Tay rt • f/f} j/ k•.. / Iv 1-..,, ,-,---1 __.... . . . . , .. .. i . ...... .. „or # *,.• ., " —� 7 . f 'FALL R ..i 'j .' / PAD :,..1,..,.-�. i g r !f 2730' FEL / I i x =`_ FALLS CREEK N0.S / 3 "'"" AS-BUILT 2 {14A.027 ASP ZONE 4 N.2269463.899 • E:240098.6V3 - LATITUDE:60"12'16.024'N ' i `ti" LONGITUDE:151'25'43.191"44� 1 -I ELEV.2430'NAVD88 J o 1908 FSL 27317 FEL I SECTION 6 T1 N R12W I . _ . _ - __.1._ . _ ..,„,„..;re LINL___, „„1 L. LV li , SCgALE 4.11 1 I I Ya:rt S1,f;YON COANCIt N:22674177.025 _ — . — -._ . CT U"1.7FTO SM- - - - - - --- - ----- - 8A915 W7rd452B SEC a i BASIS OF GEODETIC CONTROL MCI NA083 POSITION(EPOCH2003) �ErvT10NLINEOFrF.ETS E1 a TO IS AN OPUS SOLUTION FROM NGS COORDINATES STATIONS'KENS 0:1" \\ \1�) CET r i Ea FROM nEa TIR'r!.44swyau CORS ARP",'TSEA ANCHORAGE CORS ARP',AND"ZAN11 `;' I# uoruwEMB F6 rP Tr1YS ANCHORAGE\VAS 1 CORS ARP'TO ESTABLISH THE POSITION OF 1 nw.v Nur-NM FCR7. THE GEODETIC POSITION OF FRC7 WAS DETERMINED TO - I....• " I PROTRACTED I ECT dN HAVE A LATITUDE OF 60'1715 5623 5 N AND A LONGITUDE OF ;'" tj Ct ItFtPI VAtl7£s. 151'25'48 64584'W THE ALASKA STATE PLANE COORDINATES(ASP} *:.49.12 "•'.* r ZONE 4 ARE: N22691$6.:535 j >4 f E-13BE1349.866 0..........•......--..•...........— ELEV. (NA�1D681 / 2)SECTION UNE OFFSETS DETERMINED FROM MONUhAENTEd j —j SECTION CORNER VALUES, 3)NAD83 COORDINATES CONVERTED TO NAD27 WITH 11 •'-•••••29W1.4•.•....' '+ NORTH CORPSCON CONVERSION SOFTWARE VERSION 6.0-1- t r 1 N`X l\\1\�1N.♦ '''" HILCORP ALASKA LLC 'Se""S1O" ' II 31300 CENTERPOINT DR. v"..fi 1 FALLS CREEK NO.6 WELL AS-BUILT or-C MOW. ANCHORAGE,AK 99503-5826 SURFACE LOCATION DIAGRAM NAD27 / Mrw 1/01111^ tlGM u�ac E1,1,,,,,1,1061,.,Rax ON FALLS CREEK PRODUCTION PAD :AnGCT K] MWI}d INGNLWML,MPPOICrr xIlema,MIN!. ( CC*W. am •n,y..1,,,',.. P.D fr I An sau OrniA Al All G tZY+<TISk fhEEl i , r.P¢naas;v+ . r& Weds'cs1111011r' SEC.6 TIN R 121 • ` pwacou SEWARD MERIDIAN,ALASKA 1'T 1 Page 48 Version 2 Sept, 2014 Falls Creek#6 ii Drilling Procedure Hilcorp Energy Company 32.0 Offset MW vs TVD Chart Falls Creek#6 Offset Wells 0 r � kik1000Paxton#1 Paxton#2 2000 it Falls Creek#31)it.ti.111h 6.• — — Falls Creek#4 3000 0 — Fra nces#1 t.,._ Susan Dionne8 l . 4000 Falls Creek#5 i4 end- 6 (eav, ) 5000 ri_ /,;_ i.,,/v , , 5000 0 7000 d , , V 8000 I 7 A , 9000 10000 11000 12000z - 13000 14000 8 9 10 11 12 13 14 15 Mud Weight{PPG) Page 49 Version 2 Sept, 2014 Hilcorp Energy Company Ninilchik Unit Falls Creek Falls Creek #6 Falls Creek 6 Plan: Falls Creek 6 WP6.0 Standard Proposal Report 23 September, 2014 RECEIVED SEP 292014 AOGCC -IALLIBURTON Sperry Drilling Services ORIGINAL WE ULS: Falls Creek#6 HALLIBURTON Ground Level: 248.30 +N/-S +E/-W Northing Easting Latittude Longitude Slot ;perry Drilling 0.00 0.00 2269464.23 240096.85 60.20445247 -151.42867427 Project: Ninilchik Unit CASING DETAILS Hilcorp Energy Company Site: Falls Creek TVD MD Name Size Calculation Method: Minimum Curvature Well: Falls Creek#6 3407.16 3600.00 9 5/8" 9-5/8 Error System: ISCWSA 8766.80 9679.22 5 1/2" 5-1/2 Scan Method: Closest Approach 3D Wellbore: Falls Creek 6 Error Surface: Elliptical Conic Falls Creek 6 WP6.0 Warning Method: Error Ratio SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target 1 18.50 0.00 0.00 18.50 0.00 0.00 0.00 0.00 0.00 2 500.00 0.00 0.00 500.00 0.00 0.00 0.00 0.00 0.00 3 1000.00 5.00 333.77 999.37 19.56 -9.64 1.00 333.77 21.80 4 1250.00 10.00 333.77 1247.15 48.82 -24.05 2.00 0.00 54.41 5 1730.73 24.42 333.76 1705.14 176.07 -86.77 3.00 -0.02 196.23 6 7954.17 24.42 333.76 7371.74 2484.00 -1224.46 0.00 0.00 2768.45 7 8393.80 37.56 336.09 7747.80 2688.91 -1319.37 3.00 6.23 2994.28 FC6 T-60 Tgt 1500- 8 9679.22 37.56 336.09 8766.80 3405.23 -1636.95 0.00 0.00 3777.76 FC6 BHL Tgt SURVEY PROGRAM Date:2014-09-23T00:00:00 Validated:Yes Version: -750- _ Depth From Depth To Survey/Plan Tool 18.50 3600.00 Falls Creek 6 WP6.0(Falls Creek 6) MWD+SC+sag 011 3600.00 9679.22 Falls Creek 6 WP6.0(Falls Creek 6) MWD+SC+sag 0- Start Dir 1°/100':500'MD,500'TVD REFERENCE INFORMATION 750- Co-ordinate(N/E)Reference: Well Falls Creek#6,True North Vertical(ND)Reference: Falls Creek New As-built @ 266.80usft Start Dir 2°/100':1000'MD,999.37'TVD Measured Depth Reference: Falls Creek New As-built @ 266.80usft Start Dir 3°/100':1250'MD,1247.15'TVD Calculation Method: Minimum Curvature 1500- End Dir :1730.73'MD,1705.14'TVD • 2250- c - a_ in 3000- 9 5/8" LO 3750- a - a) m - U f 4500- _Beluga 135 m _ 2 5oan- Tyonek T-8 6000- T-10 Start Dir 3°/100':7954.17'MD,7371.74'TVD 6750- T-50 End Dir :8393.8'MD,7747.8'TVD 7500- T-60 1 _ FC6 T-60 Tgt 8250- T-65 FC6 BHL Tgt yp Total Depth:9679.22'MD,8766.8'ND ✓ 9000- 5 1/2" - Falls Creek 6 WP6.0 • • •-1500 -750 0 750 1500 2250 3000 3750 4500 5250 6000 ' 6750 • 7500 8250 9000 Vertical Section at 335.25°(1500 usft/in) COMPANY DETAIL corp Energy Company Project: Ninilchik Unit HALLI B U RTO N Calculation Method: Minimum Curvature Site: Falls Creek Error System:ISCWSA Well: Falls Creek#6 Scan Method: Closest Approach 3D Sperry Drilling Error Surface: Elliptical Conic • Wellbore: Falls Creek 6 Waming Method: Error Ratio Falls Creek 6 WP6.0 REFERENCE INFORMATION SECTION DETAILS Co-ordinate(N/E)Reference: Well Falls Creek#6,True North Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Vertical(TVD)Reference: Falls Creek New As-built @ 266.80usft 1 18.50 0.00 0.00 18.50 0.00 0.00 0.00 0.00 0.00 Measured Depth Reference: Falls Creek New As-built @ 266.80usft 2 500.00 0.00 0.00 500.00 0.00 0.00 0.00 0.00 0.00 Calculation Method: Minimum Curvature 31000.00 5.00 333.77 999.37 19.56 -9.64 1.00 333.77 21.80 41250.00 10.00 333.77 1247.15 48.82 -24.05 2.00 0.00 54.41 5 1730.73 24.42 333.76 1705.14 176.07 -86.77 3.00 -0.02 196.23 6 7954.17 24.42 333.76 7371.74 2484.00 -1224.46 0.00 0.00 2768.45 7 8393.80 37.56 336.09 7747.80 2688.91 -1319.37 3.00 6.23 2994.28 FC6 7-60 Tgt 8 9679.22 37.56 336.09 8766.80 3405.23 -1636.95 0.00 0.00 3777.76 FC6 BHL Tgt WELL DETAILS: Falls Creek#6 Ground Level: 248.30 +N/-S +E/-W Northing Easting Latittude Longitude Slot 0.00 0.00 2269464.23 240096.85 60.20445247 -151.42867427 3600- Falls Creek 6 WP6.0 SURVEY PROGRAM 95%cont.___ Date:2014-09-23700:00:00 Validated:Yes Version: 3400- Depth From Depth To Survey/Plan Tool 18.50 3600.00 Falls Creek 6 WP6.0(Falls Creek 6) MWD+SC+sag FC6 BHL Tgt 3600.00 9679.22 Falls Creek 6 WP6.0(Falls Creek 6) MWD+SC+sag 3200- _ 5 1/2" Total Depth:9679.22'MD,8766.8'TVD CASING DETAILS 3000- ND MD Name Size 3407.16 3600.00 9 5/T 9-5/8 8766.80 9679.22 5 1/T 5-1/2 2800- 95%conf.-__ End Dir :8393.8'MD,7747.8'TVD 2600- ti) - Start Dir 3°/100':7954.17'MD,7371.74'TVD FC6 T-60 Tgt 2400- 2200- c 0 2000- t 1800- o - a 1600- ri 1400- 1200- 1000- 9 5/8" • 800- 600- Start Dir 3°/100': 1250'MD,1247.15'TVD 400- Start Dir 2°/100':1000'MD,999.37'TVD End Dir :1730.73'MD,1705.14'TVD 200- Start Dir 10/100':500'MD,500'TVD 0- iliiiliiiiliiii � irir � iiii � iiii � iiii � iiii � iiiiliiiiliiii i � riii � 11111II1111 ii iiii I ii if -2400 -2200 -2000 -1800 -1600 -1400 -1200 -1000 -800 -600 -400 -200 0 200 400 600 800 1000 1200 West(-)/East(+)(500 usft/in) HALLI B U R TO N ,est(-)amu+)(150 usft/in) -120 -60 0 60 120 180 240 300 Project: Ninilchik Unit Site: Falls Creek Well: Falls Creek#6 240 Wellbore: Falls Creek 6 Falls Creek 6 WP6.0 180 0 I 120 2 0 60 Falls Creek#3 Falls'Creek#1 e c -60 3740— _ Falls Creek 6 WP6.0 120 3400— 9161- Falls C eek #4 -- Falls Creek 5 3060— _ 2720— 2380— ,IapO 2040- - 1700— _ 5000 1360— :C' ike o 1020— v) oo • 680— C 3p0 zzern alts-Creek tt� p0 ▪ 340— o� o cS' 01 G ~ O O 0— X00 N. o0 0 ,0 00 4> 9 F, oa- 1000 Falls Creek#I RD Oo o c o -340— 0 0 0 0 $O -680 - . .ree•-•3 o r !SO O p -1020 _Falls Creek#4 yo _ 00 1360— sells Creek 5 -1700 -2040— -2380— I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 1 1 1 I I I I I I I I I I I I I I I 1 1 I 1 I 1 1 I I I I I I I 1 1 1 1 1 1 1 1 ! I I I -3740 -3400 -3060 -2720 -2380 -2040 -1700 -1360 -1020 -680 -340 0 340 680 1020 1360 1700 2040 2380 West(-)/East(+)(850 usft/in) Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Falls Creek#6 Company: Hilcorp Energy Company TVD Reference: Falls Creek New As-built @ 266.80usft Project: Ninilchik Unit MD Reference: Falls Creek New As-built @ 266.80usft • Site: Falls Creek North Reference: True Well: Falls Creek#6 Survey Calculation Method: Minimum Curvature • Wellbore: Falls Creek 6 Design: Falls Creek 6 WP6.0 Project Ninilchik Unit • 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 04Using geodetic scale factor Site Falls Creek Site Position: Northing: 2,269,493.23 usft Latitude: 60.20452798 From: Map Easting: 240,032.38 usft Longitude: -151.42903197 Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -1.24° Well Falls Creek#6 Well Position +N/-S 0.00 usft Northing: 2,269,464.23 usft • Latitude: 60.20445247 +E/-W 0.00 usft Easting: 240,096.85 usft . Longitude: -151.42867427 Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: • 248.30 usft Wellbore Falls Creek 6 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2014 9/8/2014 16.70 73.21 55,240 Design Falls Creek 6 WP6.0 Audit Notes: Version: Phase: PLAN Tie On Depth: 18.50 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 18.50 0.00 0.00 335.25 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +NIS +E/-W Rate Rate Rate Tool Face (usft) (°) (°I (usft) usft (usft) (usft) (°I100usft) (1100usft) (°/100usft) (0) 18.50 0.00 0.00 18.50 -248.30 0.00 0.00 0.00 0.00 0.00 0.00 500.00 0.00 0.00 500.00 233.20 0.00 0.00 0.00 0.00 0.00 0.00 1,000.00 5.00 333.77 999.37 732.57 19.56 -9.64 1.00 1.00 0.00 333.77 1,250.00 10.00 333.77 1,247.15 980.35 48.82 -24.05 2.00 2.00 0.00 0.00 1,730.73 24.42 333.76 1,705.14 1,438.34 176.07 -86.77 3.00 3.00 0.00 -0.02 7,954.17 24.42 333.76 7,371.74 7,104.94 2,484.00 -1,224.46 0.00 0.00 0.00 0.00 8,393.80 37.56 336.09 7,747.80 7,481.00 2,688.91 -1,319.37 3.00 2.99 0.53 6.23 9,679.22 37.56 336.09 8,766.80 8,500.00 3,405.23 -1,636.95 0.00 0.00 0.00 0.00 9/23/2014 2:33.05PM Page 2 COMPASS 5000.1 Build 70 Halliburton HALLIBLJRTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Falls Creek#6 Company: Hilcorp Energy Company TVD Reference: Falls Creek New As-built @ 266.80usft Project: Ninilchik Unit MD Reference: Falls Creek New As-built @ 266.80usft Site: Falls Creek North Reference: True Well: Falls Creek#6 Survey Calculation Method: Minimum Curvature Wellbore: Falls Creek 6 Design: Falls Creek 6 WP6.0 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Veil Section (usft) (°) (0) (usft) usft (usft) (usft) (usft) (usft) -248.30 18.50 0.00 0.00 18.50 -248.30 0.00 0.00 2,269,464.23 240,096.85 0.00 0.00 100.00 0.00 0.00 100.00 -166.80 0.00 0.00 2,269,464.23 240,096.85 0.00 0.00 200.00 0.00 0.00 200.00 -66.80 0.00 0.00 2,269,464.23 240,096.85 0.00 0.00 300.00 0.00 0.00 300.00 33.20 0.00 0.00 2,269,464.23 240,096.85 0.00 0.00 400.00 0.00 0.00 400.00 133.20 0.00 0.00 2,269,464.23 240,096.85 0.00 0.00 500.00 0.00 0.00 500.00 233.20 0.00 0.00 2,269,464.23 240,096.85 0.00 0.00 Start Dir 1°/100':500'MD,500'TVD 600.00 1.00 333.77 599.99 333.19 0.78 -0.39 2,269,465.02 240,096.48 1.00 0.87 700.00 2.00 333.77 699.96 433.16 3.13 -1.54 2,269,467.39 240,095.38 1.00 3.49 800.00 3.00 333.77 799.86 533.06 7.04 -3.47 2,269,471.35 240,093.53 1.00 7.85 900.00 4.00 333.77 899.68 632.88 12.52 -6.17 2,269,476.88 240,090.95 1.00 13.95 1,000.00 5.00 333.77 999.37 732.57 19.56 -9.64 2,269,483.99 240,087.64 1.00 21.80 Start Dir 2°/100':1000'MD,999.37'TVD 1,100.00 7.00 333.77 1,098.81 832.01 28.93 -14.26 2,269,493.46 240,083.22 2.00 32.24 1,200.00 9.00 333.77 1,197.83 931.03 41.42 -20.41 2,269,506.08 240,077.34 2.00 46.16 1,250.00 10.00 333.77 1,247.15 980.35 48.82 -24.05 2,269,513.56 240,073.86 2.00 54.41 Start Dir 3°/100':1250'MD,1247.15'TVD 1,300.00 11.50 333.77 1,296.27 1,029.47 57.19 -28.18 2,269,522.01 240,069.92 3.00 63.73 1,400.00 14.50 333.76 1,393.70 1,126.90 77.36 -38.12 2,269,542.40 240,060.42 3.00 86.21 1,500.00 17.50 333.76 1,489.81 1,223.01 102.08 -50.30 2,269,567.37 240,048.77 3.00 113.76 1,600.00 20.50 333.76 1,584.35 1,317.55 131.28 -64.69 2,269,596.88 240,035.01 3.00 146.31 1,700.00 23.50 333.76 1,677.06 1,410.26 164.88 -81.26 2,269,630.82 240,019.18 3.00 183.75 1,730.73 24.42 333.76 1,705.14 1,438.34 176.07 -86.77 2,269,642.13 240,013.91 3.00 196.23 End Dir :1730.73'MD,1705.14'TVD 1,800.00 24.42 333.76 1,768.21 1,501.41 201.76 -99.44 2,269,668.09 240,001.80 0.00 224.86 1,900.00 24.42 333.76 1,859.27 1,592.47 238.84 -117.72 2,269,705.56 239,984.33 0.00 266.19 2,000.00 24.42 333.76 1,950.32 1,683.52 275.93 -136.00 2,269,743.03 239,966.86 0.00 307.52 2,100.00 24.42 333.76 2,041.37 1,774.57 313.01 -154.28 2,269,780.50 239,949.38 0.00 348.85 2,200.00 24.42 333.76 2,132.42 1,865.62 350.10 -172.56 2,269,817.97 239,931.91 0.00 390.18 2,300.00 24.42 333.76 2,223.48 1,956.68 387.18 -190.84 2,269,855.44 239,914.44 0.00 431.51 2,400.00 24.42 333.76 2,314.53 2,047.73 424.27 -209.12 2,269,892.91 239,896.96 0.00 472.84 2,500.00 24.42 333.76 2,405.58 2,138.78 461.35 -227.40 2,269,930.38 239,879.49 0.00 514.18 2,600.00 24.42 333.76 2,496.63 2,229.83 498.44 -245.68 2,269,967.85 239,862.02 0.00 555.51 2,700.00 24.42 333.76 2,587.69 2,320.89 535.52 -263.96 2,270,005.32 239,844.54 0.00 596.84 2,800.00 24.42 333.76 2,678.74 2,411.94 572.60 -282.24 2,270,042.79 239,827.07 0.00 638.17 2,900.00 24.42 333.76 2,769.79 2,502.99 609.69 -300.52 2,270,080.26 239,809.60 0.00 679.50 3,000.00 24.42 333.76 2,860.84 2,594.04 646.77 -318.80 2,270,117.73 239,792.12 0.00 720.83 3,100.00 24.42 333.76 2,951.90 2,685.10 683.86 -337.09 2,270,155.21 239,774.65 0.00 762.16 3,200.00 24.42 333.76 3,042.95 2,776.15 720.94 -355.37 2,270,192.68 239,757.18 0.00 803.49 3,300.00 24.42 333.76 3,134.00 2,867.20 758.03 -373.65 2,270,230.15 239,739.70 0.00 844.83 3,400.00 24.42 333.76 3,225.05 2,958.25 795.11 -391.93 2,270,267.62 239,722.23 0.00 886.16 3,500.00 24.42 333.76 3,316.11 /3,049.31 832.20 -410.21 2,270,305.09 239,704.75 0.00 927.49 3,600.00 24.42 333.76 3,407.16 3,140.36 869.28 -428.49 2,270,342.56 239,687.28 0.00 968.82 --, 9 5/8" • 3,700.00 24.42 333.76 3,498.21 3,231.41 906.36 -446.77 2,270,380.03 239,669.81 0.00 1,010.15 9/23/2014 2:33.'05PM Page 3 COMPASS 5000.1 Build 70 Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Falls Creek#6 Company: Hilcorp Energy Company TVD Reference: Falls Creek New As-built @ 266.80usft Project: Ninilchik Unit MD Reference: Falls Creek New As-built @ 266.80usft Site: Falls Creek North Reference: True Well: Falls Creek#6 Survey Calculation Method: Minimum Curvature Wellbore: Falls Creek 6 Design: Falls Creek 6 WP6.0 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 3,322.46 3,800.00 24.42 333.76 3,589.26 3,322.46 943.45 -465.05 2,270,417.50 239,652.33 0.00 1,051.48 3,900.00 24.42 333.76 3,680.32 3,413.52 980.53 -483.33 2,270,454.97 239,634.86 0.00 1,092.81 4,000.00 24.42 333.76 3,771.37 3,504.57 1,017.62 -501.61 2,270,492.44 239,617.39 0.00 1,134.14 4,100.00 24.42 333.76 3,862.42 3,595.62 1,054.70 -519.89 2,270,529.91 239,599.91 0.00 1,175.48 4,200.00 24.42 333.76 3,953.47 3,686.67 1,091.79 -538.17 2,270,567.38 239,582.44 0.00 1,216.81 4,300.00 24.42 333.76 4,044.53 3,777.73 1,128.87 -556.45 2,270,604.85 239,564.97 0.00 1,258.14 4,400.00 24.42 333.76 4,135.58 3,868.78 1,165.95 -574.73 2,270,642.32 239,547.49 0.00 1,299.47 4,500.00 24.42 333.76 4,226.63 3,959.83 1,203.04 -593.01 2,270,679.79 239,530.02 0.00 1,340.80 4,600.00 24.42 333.76 4,317.68 4,050.88 1,240.12 -611.30 2,270,717.26 239,512.55 0.00 1,382.13 4,700.00 24.42 333.76 4,408.74 4,141.94 1,277.21 -629.58 2,270,754.73 239,495.07 0.00 1,423.46 4,800.00 24.42 333.76 4,499.79 4,232.99 1,314.29 -647.86 2,270,792.20 239,477.60 0.00 1,464.80 4,900.00 24.42 333.76 4,590.84 4,324.04 1,351.38 -666.14 2,270,829.67 239,460.13 0.00 1,506.13 5,000.00 24.42 333.76 4,681.89 4,415.09 1,388.46 -684.42 2,270,867.14 239,442.65 0.00 1,547.46 5,100.00 24.42 333.76 4,772.95 4,506.15 1,425.55 -702.70 2,270,904.61 239,425.18 0.00 1,588.79 5,200.00 24.42 333.76 4,864.00 4,597.20 1,462.63 -720.98 2,270,942.08 239,407.70 0.00 1,630.12 5,246.13 24.42 333.76 4,906.00 4,639.20 1,479.74 -729.41 2,270,959.37 239,399.64 0.00 1,649.19 Beluga 135 5,300.00 24.42 333.76 4,955.05 4,688.25 1,499.71 -739.26 2,270,979.56 239,390.23 0.00 1,671.45 5,400.00 24.42 333.76 5,046.10 4,779.30 1,536.80 -757.54 2,271,017.03 239,372.76 0.00 1,712.78 5,500.00 24.42 333.76 5,137.16 4,870.36 1,573.88 -775.82 2,271,054.50 239,355.28 0.00 1,754.11 5,523.99 24.42 333.76 5,159.00 4,892.20 1,582.78 -780.21 2,271,063.49 239,351.09 0.00 1,764.03 Tyonek 5,600.00 24.42 333.76 5,228.21 4,961.41 1,610.97 -794.10 2,271,091.97 239,337.81 0.00 1,795.45 5,700.00 24.42 333.76 5,319.26 5,052.46 1,648.05 -812.38 2,271,129.44 239,320.34 0.00 1,836.78 5,800.00 24.42 333.76 5,410.31 5,143.51 1,685.14 -830.66 2,271,166.91 239,302.86 0.00 1,878.11 5,900.00 24.42 333.76 5,501.37 5,234.57 1,722.22 -848.94 2,271,204.38 239,285.39 0.00 1,919.44 6,000.00 24.42 333.76 5,592.42 5,325.62 1,759.31 -867.23 2,271,241.85 239,267.92 0.00 1,960.77 6,100.00 24.42 333.76 5,683.47 5,416.67 1,796.39 -885.51 2,271,279.32 239,250.44 0.00 2,002.10 6,200.00 24.42 333.76 5,774.52 5,507.72 1,833.47 -903.79 2,271,316.79 239,232.97 0.00 2,043.43 6,300.00 24.42 333.76 5,865.58 5,598.78 1,870.56 -922.07 2,271,354.26 239,215.50 0.00 2,084.76 6,318.04 24.42 333.76 5,882.00 5,615.20 1,877.25 -925.36 2,271,361.02 239,212.34 0.00 2,092.22 T-8 6,400.00 24.42 333.76 5,956.63 5,689.83 1,907.64 -940.35 2,271,391.73 239,198.02 0.00 2,126.10 6,500.00 24.42 333.76 6,047.68 5,780.88 1,944.73 -958.63 2,271,429.20 239,180.55 0.00 2,167.43 6,600.00 24.42 333.76 6,138.73 5,871.93 1,981.81 -976.91 2,271,466.67 239,163.08 0.00 2,208.76 6,627.75 24.42 333.76 6,164.00 5,897.20 1,992.10 -981.98 2,271,477.07 239,158.23 0.00 2,220.23 T-10 6,700.00 24.42 333.76 6,229.79 5,962.99 2,018.90 -995.19 2,271,504.14 239,145.60 0.00 2,250.09 6,800.00 24.42 333.76 6,320.84 6,054.04 2,055.98 -1,013.47 2,271,541.61 239,128.13 0.00 2,291.42 6,900.00 24.42 333.76 6,411.89 6,145.09 2,093.07 -1,031.75 2,271,579.08 239,110.65 0.00 2,332.75 7,000.00 24.42 333.76 6,502.94 6,236.14 2,130.15 -1,050.03 2,271,616.55 239,093.18 0.00 2,374.08 7,100.00 24.42 333.76 6,594.00 6,327.20 2,167.23 -1,068.31 2,271,654.02 239,075.71 0.00 2,415.42 7,200.00 24.42 333.76 6,685.05 6,418.25 2,204.32 -1,086.59 2,271,691.49 239,058.23 0.00 2,456.75 7,300.00 24.42 333.76 6,776.10 6,509.30 2,241.40 -1,104.87 2,271,728.96 239,040.76 0.00 2,498.08 7,400.00 24.42 333.76 6,867.15 6,600.35 2,278.49 -1,123.15 2,271,766.44 239,023.29 0.00 2,539.41 9/23/2014 2:33.05PM Page 4 COMPASS 5000.1 Build 70 Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Falls Creek#6 Company: Hilcorp Energy Company TVD Reference: Falls Creek New As-built @ 266.80usft Project: Ninilchik Unit MD Reference: Falls Creek New As-built @ 266.80usft Site: Falls Creek North Reference: True Well: Falls Creek#6 Survey Calculation Method: Minimum Curvature Wellbore: Falls Creek 6 Design: Falls Creek 6 WP6.0 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 6,691.41 7,500.00 24.42 333.76 6,958.21 6,691.41 2,315.57 -1,141.44 2,271,803.91 239,005.81 0.00 2,580.74 7,600.00 24.42 333.76 7,049.26 6,782.46 2,352.66 -1,159.72 2,271,841.38 238,988.34 0.00 2,622.07 7,700.00 24.42 333.76 7,140.31 6,873.51 2,389.74 -1,178.00 2,271,878.85 238,970.87 0.00 2,663.40 7,800.00 24.42 333.76 7,231.36 6,964.56 2,426.83 -1,196.28 2,271,916.32 238,953.39 0.00 2,704.73 7,900.00 24.42 333.76 7,322.42 7,055.62 2,463.91 -1,214.56 2,271,953.79 238,935.92 0.00 2,746.07 7,954.17 24.42 333.76 7,371.74 7,104.94 2,484.00 -1,224.46 2,271,974.09 238,926.45 0.00 2,768.45 Start Dir 3°/100':7954.17'MD,7371.74'TVD 8,000.00 25.79 334.10 7,413.24 7,146.44 2,501.47 -1,233.00 2,271,991.73 238,918.29 3.00 2,787.89 8,038.80 26.95 334.37 7,448.00 7,181.20 2,516.98 -1,240.49 2,272,007.41 238,911.14 3.00 2,805.12 T-50 8,100.00 28.77 334.75 7,502.11 7,235.31 2,542.81 -1,252.78 2,272,033.50 238,899.42 3.00 2,833.72 8,200.00 31.76 335.28 7,588.46 7,321.66 2,588.50 -1,274.06 2,272,079.63 238,879.13 3.00 2,884.12 8,298.69 34.71 335.72 7,671.00 7,404.20 2,637.72 -1,296.48 2,272,129.32 238,857.77 3.00 2,938.21 T-60 8,300.00 34.75 335.73 7,672.07 7,405.27 2,638.40 -1,296.79 2,272,130.01 238,857.48 3.00 2,938.95 8,393.80 37.56 336.09 7,747.80 7,481.00 2,688.91 -1,319.37 2,272,181.00 238,836.00 3.00 2,994.28 End Dir :8393.8'MD,7747.8'TVD 8,400.00 37.56 336.09 7,752.72 7,485.92 2,692.37 -1,320.91 2,272,184.49 238,834.54 0.00 2,998.06 8,500.00 37.56 336.09 7,831.99 7,565.19 2,748.10 -1,345.61 2,272,240.73 238,811.05 0.00 3,059.01 8,600.00 37.56 336.09 7,911.26 7,644.46 2,803.82 -1,370.32 2,272,296.98 238,787.55 0.00 3,119.96 8,700.00 37.56 336.09 7,990.54 7,723.74 2,859.55 -1,395.03 2,272,353.23 238,764.06 0.00 3,180.91 8,800.00 37.56 336.09 8,069.81 7,803.01 2,915.27 -1,419.73 2,272,409.47 238,740.56 0.00 3,241.86 8,806.55 37.56 336.09 8,075.00 7,808.20 2,918.92 -1,421.35 2,272,413.15 238,739.02 0.00 3,245.85 1-65 8,900.00 37.56 336.09 8,149.08 7,882.28 2,971.00 -1,444.44 2,272,465.72 238,717.07 0.00 3,302.81 9,000.00 37.56 336.09 8,228.36 7,961.56 3,026.72 -1,469.15 2,272,521.96 238,693.57 0.00 3,363.77 9,100.00 37.56 336.09 8,307.63 8,040.83 3,082.45 -1,493.86 2,272,578.21 238,670.08 0.00 3,424.72 9,200.00 37.56 336.09 8,386.90 8,120.10 3,138.17 -1,518.56 2,272,634.45 238,646.58 0.00 3,485.67 9,300.00 37.56 336.09 8,466.18 8,199.38 3,193.90 -1,543.27 2,272,690.70 238,623.09 0.00 3,546.62 9,400.00 37.56 336.09 8,545.45 8,278.65 3,249.62 -1,567.98 2,272,746.95 238,599.59 0.00 3,607.57 9,500.00 37.56 336.09 8,624.72 8,357.92 3,305.35 -1,592.68 2,272,803.19 238,576.10 0.00 3,668.52 9,600.00 37.56 336.09 8,704.00 8,437.20 3,361.07 -1,617.39 2,272,859.44 238,552.60 0.00 3,729.47 9,679.22 37.56 336.09 8,766.80 8,500.00 3,405.22 -1,636.96 2,272,903.99 238,533.99 0.00 3,777.75 Total Depth:9679.22'MD,8766.8'TVD-5 1/2" Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +El-W Northing Easting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) FC6 BHL Tgt 0.00 0.00 8,766.80 3,405.23 -1,636.95 2,272,904.00 238,534.00 -plan misses target center by 0.01 usft at 9679.22usft MD(8766.80 TVD,3405.22 N,-1636.96 E) -Circle(radius 100.00) FC6 T-60 Tgt 0.00 0.00 7,747.80 2,688.91 -1,319.37 2,272,181.00 238,836.00 -plan hits target center -Circle(radius 100.00) 9/23/2014 2:33.05PM Page 5 COMPASS 5000.1 Build 70 Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Falls Creek#6 Company: Hilcorp Energy Company TVD Reference: Falls Creek New As-built @ 266.80usft Project: Ninilchik Unit MD Reference: Falls Creek New As-built @ 266.80usft Site: Falls Creek North Reference: True Well: Falls Creek#6 Survey Calculation Method: Minimum Curvature Wellbore: Falls Creek 6 Design: Falls Creek 6 WP6.0 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 3,600.00 3,407.16 9 5/8" 9-5/8 12-1/4 9,679.22 8,766.80 51/2" 5-1/2 8-1/2 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (usft) (usft) Name Lithology co) r) 6,627.75 6,164.00 T-10 8,806.55 8,075.00 T-65 8,298.69 7,671.00 T-60 I 5,523.99 5,159.00 Tyonek 8,038.80 7,448.00 T-50 5,246.13 4,906.00 Beluga 135 6,318.04 5,882.00 T-8 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +EI-W (usft) (usft) (usft) (usft) Comment 500.00 500.00 0.00 0.00 Start Dir 1°/100':500'MD,500'TVD 1,000.00 999.37 19.56 -9.64 Start Dir 2°/100':1000'MD,999.37'TVD 1,250.00 1,247.15 48.82 -24.05 Start Dir 3°/100':1250'MD,1247.15'TVD 1,730.73 1,705.14 176.07 -86.77 End Dir :1730.73'MD,1705.14'TVD 7,954.17 7,371.74 2,484.00 -1,224.46 Start Dir 3°/100':7954.17'MD,7371.74'TVD 8,393.80 7,747.80 2,688.91 -1,319.37 End Dir :8393.8'MD,7747.8'TVD 9,679.22 8,766.80 3,405.22 -1,636.96 Total Depth:9679.22'MD,8766.8'ND 9/23/2014 2:33.'05PM Page 6 COMPASS 5000.1 Build 70 N e. m u L r 01 o' m C Ma L 0 QL L I at N an 0 L v :- a_ N c O tU L R c O w CD Ii u <O a c3 "' aN co(aa 2o d ‘°-,c `4 — 0 C In cG : 'eN 14 U TixR• Ote_ N Q. t B + LL 2 oo _ • N E _ m R Y O c w p : m p O m V ^ N = cod 00 + fn IL tOD O O. 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I fl I ,1 I Q Lc) CO I I I 0 h `° `o u I0 a O To I N u_CO 0 C CL a CD E.' 1:1- I O Lu W I I I r ,3) , I I I p iv C o ` 0 0 CO It N I I 9 N N V ` 9,� o N I I I CO ,Z Q v I I s- 2 N c 0 I I U © g N I N C z 7 n I I I' o N m I I I Z Q x I a> N LL c I I „I��' 40L Z I LO CO ~o Y, ',T, I I ' Q N > U I I III�j� i} cp C Q ' m „s, I I I 1'1 M a a� m I I 4 L� N .2 N I =%111 U> o I I I I i al c m 0 D o� I I I O O Q C N v o d oJ > 8 hi aJ s O _ o cN4 o (u / jsn 05c) uogeedes aTua3 o} a }ue° = 5f oa 0 > U U a E al E ; tUrtIVCV STATE OF ALASKA SEP 1 7 2014 • AL :A OIL AND GAS CONSERVATION COMM ON PERMIT TO DRILL AOGCC 20 AAC 25.005 la.Type of Work: lb.Proposed Well Class: Development-Oil ❑ Service- Winj ❑ Single Zone Q . lc.Specify if well is proposed for: Drill " Q Lateral ❑ Stratigraphic Test ❑ Development-Gas 2 • Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates D Redril❑ Reentry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Q . Single Well ❑ 11.Well Name and Number: Hilcorp Alaska,LLC Bond No. 022035244 ' Falls Creek#6 • 3.Address: 6.Proposed Depth: 127ield/Pool(s): 3800 Centerpoint Drive,Suite 1400,Anchorage AK 99503 MD: 9,558' • TVD: 8,690' . ,' Ninilchick 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Az. f)stb FC Tyonek Undef Gas • Surface: 1831'FSL,2895'FEL,Sec 6,Ti N,R12W,SM AK ' Fee- -t—ml L 384314(BHL);ADL- a(TPI) Ah ./ ,,yo,' Top of Productive Horizon: 8.Land Use Permit: ,! 13.Approximate Spud Date: 2418'FNL, 1892'FWL,Sec 6,TIN,R12W,SM,AK NA / _ 10/24/2014 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 38'FSL,857'FWL,Sec 31,T2N,R12W,SM,AK ADL 384314=35113. 5 acres . -310 ft from TPI to Unit Tract 51A 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above M it//' • 267.5 feet 15.Distance to Nearest Well Open Surface: x-239932.3 ' y-2269393.2 " Zone-4 GL Elevation abov N I/ • 248.9'feet to Same Pool: 3386' 16.Deviated wells: Kickoff depth: 100 feet • 17.Maximum Ant i a /Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 38 degrees . Downhole: 373 i Surface: 2868 psi • 18.Casing Program: Specifications Top - ting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length M 1 TVD MD TVD (including stage data) Gond 16" 109 X-56 Weld 80' Surfa Surface 80' 80' Driven 12-1/4" 9-5/8" 40 L-80 BTC 3,500' Surface/ Surface 3,500' . 3,289' 313.4bbls/1761ft3 8-1/2" 5-1/2" 17 P-110 CDC 9,558' \ ur Surfacre Surface 9,558' • 8,690' 346.3bbls/1944.3ft3 V 19. PRESENT WELL CONDITION SUMMARY(To ompleted for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(mea re . / Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate di \,/ Production '01i Liner 1/' Perforation Depth MD(ft): V, Perforation Depth TVD(ft): 20. Attachments: Property Plat Q =//9P SketchQ Drilling Program 0Time v.Depth Plot E Shallow Hazard Analysis❑ •iyt:rter Sketch Q Seabed Report ❑ Drilling Fluid Program [ ' 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representaty(r/e: Date 22. I hereby certify that the foregoing is true rd correct. Contact Luke Keller / Email Ikeller(a hilcorp.com :::::ame ja1DllingEngineer Phone 907-777-8395 Date 9/17/2014 Commission Use Only Permit to Drill . / API Number: � t / Permit Approval See cover letter for other Number: , Z(`t / 7 50-/ �2L ) SI.. 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: [✓i Other: y S` is�P •�1.-- Samples req'd: Yes❑ No Mud log req'd:Yes❑ No[� -k 1 /'� H2S measures: Yes❑ No[ Directional svy req'd:Yes[ No -f l� rei � Spacing exception req'd: Yes a[ to ri, 7 Inclination-only svy yeq'd:Yes❑ No L.� ` S „- lar ` // vt/r��C `pf-rov o� w<n,/�Lc( /��GC'�i`-� � �`I /. /J 'T6 Cd vr.(U� i.' 7 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: G `'26'11 ^ n f N Submit Form and Form 10-401(Bevis 1012012) This s r f r h from the date of approval(20 AAC 25.00518))�Att(a�chments in�u lica e Luke Keller Hilcorp Alaska, LLC Drilling Engineer P.O. Box 244027 Anchorage,AK 99524-4027 Tel 907 777 8395 Email Ikeller@hilcorp.com Hikorl)Alarkn,LLC 9/17/14 A -i E afJ E .s=ay SEP 17 2014 Commissioner Alaska Oil & Gas Conservation Commission CC 333 W. 7th Avenue " " Anchorage, Alaska 99501 Re: Falls Creek#6 Dear Commissioner, Enclosed for review and approval is the application for the Permit to Drill the Falls Creek #6 development gas well. • Falls Creek#6 is a 9558' MD Tyonek and Beluga gas development well planned to be drilled from the existing Falls Creek pad. Subsurface and 3D seismic control indicate flat structure to the northeast of the Falls Creek 1RD, which has cumulated over 20 BCFG from predominately the Tyonek Formation. In addition, seismic indicates a T-50/T-60 stratigraphic thick--similar to that observed in the recently completed Frances 1 well in the same reservoir unit. In addition, an AVO anomaly has been mapped at the T-60 take point. The wellbore is planned as a build and hole wellbore with a shallow kick off at 100' to gain separation from the existing wells on the pad. • Maximum hole angle will be 38 degrees near TD. Drilling operations are expected to commence approximately Oct 24th, 2014. The Saxon Rig# 147 will be used to drill the well and run the 5-1/2"long string. All known potential fresh water zones exist above 200'. This information is based off salinity calculations of neighboring water wells. Chlorides are 1100 ppm at the 171 — 194' sand, 1800 ppm at the 505 — 535' sand, and 6000 ppm at the 1040' sand. Furthermore, the TGAS (total gas) curve from offset mud logs begins registering shallow gas at depths just below the sandstone bed at 200'. Surface casing will be run to 3,500' MD/3,289' TVD and cemented to surface to ensure protection of these resources. Cement returns to surface will confirm TOC at surface. If cmt returns to surface are not observed, a Temp log will be run between 6 — 18 hrs after CIP to determine TOC. Necessary remedial action will then be discussed with AOGCC authorities. Hilcorp Alaska, LLC Page 1 of 2 All waste & mud generated during drilling and completion operations will be hauled to the Kenai Gas Field G&I facility for disposal/beneficial reuse depending on test results. General sequence of operations: 1. MOB Saxon Rig# 147 to well site 2. N/U 16-3/4" conductor riser. 4- 3. 3. Drill 12-1/4"hole to 3500' MD. Run and cmt 9-5/8" surface casing. 4. N/D conductor riser,N/U &test 11"x 5M T3-Energy BOP. 5. Drill 8-1/2"hole section to 9,558' MD. Run wireline logs. Run and cmt 5-1/2" production casing. 6. N/D BOP,N/U temp abandonment cap, RDMO. Reservoir Evaluation Plan: 1. Surface hole: No open hole logs planned. 7 cyr G4 s��`�l ��mss �k �-�c� 9, i7 2. Production Hole: LWD: GR+Res+Den/Neu (Triple Combo). Open hole wireline logging—Dipole sonic. ✓ C.aL 3. Mud loggers from surface casing point to TD. If you have any questions, please don't hesitate to contact myself at 777-8395 or Paul Mazzolini at 777-8369. Sincerely, Luke Keller Drilling Engineer Hilcorp Alaska, LLC Page 2 of 2 Hilcorp Alaska, LLC Falls Creek #6 Drilling Program Version 1 Sept 12th, 2014 • Hilcorp Falls Creek#6 Drilling Procedure Energy Company Contents 1.0 Well Summary 2 2.0 Management of Change Information 3 3.0 Tubular Program: 4 4.0 Drill Pipe Information: 4 5.0 Internal Reporting Requirements 5 6.0 Planned Wellbore Schematic 6 7.0 Drilling/Completion Summary 7 8.0 Mandatory Regulatory Compliance/Notifications 8 9.0 R/U and Preparatory Work 10 10.0 N/U 21-1/4"2M Diverter System 11 11.0 Drill 12-1/4" Hole Section 13 12.0 Run 9-5/8" Surface Casing 17 13.0 Cement 9-5/8" Surface Casing 20 14.0 BOP N/U and Test 23 15.0 Drill 8-1/2" Hole Section 24 16.0 Run 5-1/2" Production Casing 29 17.0 Cement 5-1/2" Production Casing 32 18.0 RDMO 35 19.0 Perf and Frac 35 20.0 BOP Schematic 36 21.0 Wellhead Schematic 37 22.0 Days Vs Depth 38 23.0 Formation Tops 39 24.0 Anticipated Drilling Hazards 40 25.0 Saxon Rig 147 Layout 42 26.0 FIT Procedure 43 27.0 Choke Manifold Schematic 44 28.0 Casing Design Information 45 29.0 8-1/2"Hole Section MASP 46 30.0 Spider Plot(NAD 27)(Governmental Sections) 47 31.0 Surface Plat(As Staked)(NAD 27) 48 32.0 Offset MW vs TVD Chart 49 Falls Creek#6 Drilling Procedure Hilcorp Energy Company 1.0 Well Summary Well Falls Creek#6 Pad Falls Creek Planned Completion Type 2-7/8"prod tubing inside 5-1/2"production casing Target Reservoir(s) Beluga 135,Tyonek, T-8, T-10, T-50, T-60, T-65 Planned Well TD, MD/TVD 9,558' MD/8,690' TVD PBTD,MD/TVD 9,400' MD/8,564' TVD Surface Location(Governmental) 1831' FSL,2895' FEL, Sec 6, T1N,R12W, SM AK Surface Location(NAD 27) X=239932.3,Y=2269393.2 Surface Location(NAD 83) Top of Productive Horizon (Governmental) 2418'FNL, 1892'FWL, Sec 6, T1N,R12W, SM,AK TPH Location(NAD 27) X=239515.43,Y=2270425.76 TPH Location(NAD 83) BHL(Governmental) 38'FSL, 857'FWL, Sec 31,T2N,R12W, SM,AK BHL(NAD 27) X=238534,Y=2272904 BHL(NAD 83) AFE Number 1413027D AFE Drilling Days 32 AFE Completion Days AFE Drilling Amount $5,425,934 AFE Completion Amount Maximum Anticipated Pressure (Surface) 2868 psi (100%evacuation to 0.1 psi/ft gradient) Maximum Anticipated Pressure (Downhole/Reservoir) 3737 psi Work String 4-1/2" 16.6# S-135 CDS-40 KB Elevation above MSL: 248.9' + 18.6' =267.5' GL Elevation above MSL: 248.9' NAVD88 BOP Equipment 11" 5M T3-Energy Annular BOP 11" 5M T3-Energy Double Ram 11" 5M T3-Energy Single Ram Page 2 Version 1 Sept,2014 Falls Creek#6 TDrilling Procedure Hilcorp Energy Company 2.0 Management of Change Information Hilcorp Alaska, LLC Hilcorp Enemy Comoro' Changes to Approved Permit to Drill Date: Subject: Changes to Approved Permit to Drill for Falls Creek #6 File#: Falls Creek #6 Drilling and Completion Program Any modifications to Falls Creek#6 Drilling completion Program will be documented and approved below. Changes to an approved APD will b ...r. a-the BLII and AOGCC. �t!i�-ez f_ Ire/kce S-7) i7 /7 Sec Page Date Procedure Change Approved Approved By By Approval: Drilling Manager Date Prepared: Drilling Engineer Date Page 3 Version 1 Sept, 2014 • Falls Creek#6 Drilling Procedure Hilcorp Energy Company 3.0 Tubular Program: Hole in) ID(in) Drift Conn Wt Grade kn Burst Collapse Tension Section (in) OD (in) (#/ft) (psi)._: (psi) (k-lbs) Cond 16" 15" - - 109 X-56 Weld 12-1/4" 9-5/8" 8.835" 8.75" 10.625" 40 L-80 BTC 5750 ✓ 3090 916 8-1/2" 5-1/2" 4.892" 4.767" 6.05" 17 P-110 CDC 10600 `/ 8730 545 4.0 Drill Pipe Information: Hole OD (in) ID (in) TJ ID TJ OD Wt Grade Conn Burst Collapse Tension Section (in) (in) (#/ft) _ (psi) .:: (psi) (k-lbs)_t All 4.5" 3.826 2.6875" 5.25" 16.6 S-135 CDS40 17,693 16,769 468k All casing will be new, PSL 1 (100%mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 4 Version 1 Sept, 2014 t ii Falls Creek#6 Drilling Procedure Hilcorp Eneru Company 5.0 Internal Reporting Requirements 5.1 Fill out daily drilling report and cost report on Wellez. • Report covers operations from 6am to 6am • Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area—this will not save the data entered, and will navigate to another data entry tab. • Ensure time entry adds up to 24 hours total. • Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. 5.2 Afternoon Updates • Submit a short operations update each work day to pmazzolini@hilcorp.com , lkeller@hilcorp.com andjbarrett@hilcorp.com 5.3 Intranet Home Page Morning Update • Submit a short operations update each morning by 7am on the company intranet homepage. On weekend and holidays, ensure to have this update in before 5am. Each rig will be assigned a username to login with. 5.4 EHS Incident Reporting • Notify EHS field coordinator. 1. This could be one of(3) individuals as they rotate around. Know who your EHS field coordinator is at all times, don't wait until an emergency to have to call around and figure it out!!!! a. John Coston: 0: (907) 777-6726 C: (907)227-3189 b. Mark Tornai: 0: (907)283-1372 C: (907) 748-3299 c. Thad Eby: 0: (907) 777-8317 C: (907)602-5178 2. Spills: Kate Kaufman: 0:907-777-8329 C:907-244-8292 • Notify Drlg Manager 1. Paul Mazzolini: 0: 907-777-8369 C: 907-317-1275 • Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally • Send final "As-Run"Casing tally to lkeller@hilcorp.com and jbarrett@hilcorp.com 5.6 Casing and Cmt report • Send casing and cement report for each string of casing to lkeller@hilcorp.com and jbarrett@hilcorp.com Page 5 Version 1 Sept, 2014 DR y)pE DETAIL55 PPEst PP:Pressure2212l054-4-112112E5:727 H Hilcorp r Falls Creek#6 Drilling Procedure Energy Company 6.0 Planned Wellbore Schematic CASING DE-AIL ; :741 ',DI* Size Type ',.'.. L,ra-..:e L.7_,r- ;,E c;: E,'..7. '5' dier% t,0 ..w ,.. Conductor- is Driven to 5et lc; x..s. V,E: le 5,,-f Depth •,t Surf.Cs 42 L-E: ETC E HE SL'rf 1.3.2:' 6.6 cog 5-12 Prod Cauni. 17 F-112 CE•C 4 Elz: 5L,rf : .;,555' 9.5 ppg )- Production 5.4 L-E: 1ST :-4-4C 5f 5222' i 4.: "IOC at 9-5?3" t:.: ' ,7,4'77%, 1 • Drilling Info 4, Hole Section Casing _ FM' Wpriiktri.m .r, -'': ' . ''•'-' .- 1, ::..-0.74i3e n t 5.27 0 43 N.,:,. OD Item 1 150' SCSSV 2 4800' CIM 3 5000 Prod Pkr 4 5020 Wireline re-entry guide Hole ;:... ' - Planned Reservoir Objectives 5,555 5,882 2,529 6.27 0 43 . - . , T-1D 6,665 6,164 2,651 5.27 0 43 -.. T-57 5,229 7,448 8,20! 5.27 0.43 06 T-5D 5,463 7,671 E*2..r::::,ra,::.7.D5128:-plillt 2I-'1_4'o'55p,,47(45tviD)I D 5-9-T-15:102845Wp:..',9E9L- 3,299 5.07 0.45 T-55 5,665 5,075 3,470 6.27 0.43 ? _- I • ____ 1 _ i t, - - • t . 5_1' PBTD=9.400'3.ID..'8.564'TVD TD=9,558:AD/8,690'TVD Page 6 Version 1 Sept, 2014 Falls Creek#6 Drilling Procedure Hilcorp Energy Company 7.0 Drilling / Completion Summary Falls Creek#6 is a 9558'MD Tyonek and Beluga gas development well planned to be drilled from the existing Falls Creek pad. Subsurface and 3D seismic control indicate flat structure to the northeast of the Falls Creek 1RD,which has cumulated over 20 BCFG from predominately the Tyonek Formation. In addition, seismic indicates a T-50/T-60 stratigraphic thick--similar to that observed in the recently completed Frances 1 well in the same reservoir unit. In addition, an AVO anomaly has been mapped at the T-60 take point. The wellbore is planned as a build and hole wellbore with a shallow kick off at 100' to gain separation from the existing wells on the pad. Maximum hole angle will be 38 degrees near TD. • Drilling operations are expected to commence approximately Oct 24th, 2014. • The Saxon Rig# 147 will be used to drill the well and run the 5-1/2" long string. All known potential fresh water zones exist above 200'. This information is based off salinity calculations of neighboring water wells. Chlorides are 1100 ppm at the 171 — 194' sand, 1800 ppm at the 505 — 535' sand, and 6000 ppm at the 1040' sand. Furthermore, the TGAS (total gas) curve from offset mud logs begins registering shallow gas at depths just below the sandstone bed at 200'. • Surface casing will be run to 3,500' MD/3,289' TVD and cemented to surface to ensure protection of these resources. Cement returns to surface will confirm TOC at surface. If cmt returns to surface are not observed, a Temp log will be run between 6 — 18 hrs after CIP to determine TOC. Necessary remedial action will then be discussed with AOGCC authorities. All waste &mud generated during drilling and completion operations will be hauled to the Kenai Gas Field G&I facility for disposal/beneficial reuse depending on test results. General sequence of operations: 1. MOB Saxon Rig# 147 to well site 2. N/U 16-3/4"conductor riser. 3. Drill 12-1/4"hole to 3500' MD. Run and cmt 9-5/8" surface casing. 4. N/D conductor riser,N/U &test 11"x 5M T3-Energy BOP. 5. Drill 8-1/2"hole section to 9,558' MD. Run wireline logs. Run and cmt 5-1/2"production casing. 6. N/D BOP,N/U temp abandonment cap, RDMO. Reservoir Evaluation Plan: 1. Surface hole: No open hole logs planned. 2. Production Hole: LWD: GR+Res+Den/Neu(Triple Combo). Open hole wireline logging— Dipole sonic. 3. Mud loggers from surface casing point to TD. Page 7 Version 1 Sept, 2014 Falls Creek#6 Drilling Procedure Hilcorp Energy Company 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with the below AOGCC regulations. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. • BOPs shall be tested at (2) week intervals during the drilling and completion of Falls Creek#6. Ensure to provide AOGCC 24 hrs notice prior to testing BOPs. • The initial test of BOP equipment will be to 250/3500 psi & subsequent tests of the BOP equipment will be to 250/3500 psi for 5/5 min(annular to 50%rated WP, 2500 psi on the high test for initial and subsequent tests). Confirm that these test pressures match those specified on the APD. • If the BOP is used to shut in on the well in a well control situation, we must test all BOP components utilized for well control prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP test. • All AOGCC regulations within 20 AAC 25.033 "Primary well control for drilling: drilling fluid program and drilling fluid system". • All AOGCC regulations within 20 AAC 25.035 "Secondary well control for primary drilling and completion: blowout prevention equipment and diverter requirements". • Ensure AOGCC approved drilling permit is posted on the rig floor and in Co Man office. AOGCC Regulation Variance Requests: • There are no variance requests at this time. ✓ Page 8 Version 1 Sept, 2014 Falls Creek#6 Drilling Procedure Hilcorp Energy Company Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure(psi) 12-1/4" • 21-1/4"2M diverter w/16"diverter line Function Test Only • 11"x 5M T3-Energy(Model 7082)Annular BOP • 11"x 5M T3-Energy Double Ram Initial Test:250/3500 o Blind ram in btm cavity (Annular 2500 psi) • Mud cross 8-1/2" • 11"x 5M T-3 Energy Single Ram • 3-1/8"5M Choke Line Subsequent Tests: • 2-1/16"x 5M Kill line 250/3500 • 3-1/8"x 2-1/16"5M Choke manifold (Annular 2500 psi) • Standpipe,floor valves,etc • Primary closing unit: Control Technologies accumulator unit, 5 station, 120 gallon(12 x 11 gal bottles). • Primary closing hydraulic pressure is provided by an electrically driven triplex pump. Emergency pressure is provided by bottled nitrogen. Required AOGCC Notifications: • Well control event(BOPs utilized to shut in the well to control influx of formation fluids). • 24 hours notice prior to spud. • 24 hours notice prior to testing BOPs. • 24 hours notice prior to casing running& cement operations. • Any other notifications required in APD. Regulatory Contact Information: AOGCC Jim Regg/AOGCC Inspector/(0): 907-793-1236/Email:jim.regg@alaska.gov Guy Schwartz/Petroleum Engineer/(0): 907-793-1226/(C): 907-301-4533 /Email:guy.schwartz(a,alaska.gov Victoria Ferguson/Petroleum Engineer/(0): 907-793-1247/Email: Victoria.ferguson(iialaska.gov Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov Test/Inspection notification standardization format: http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html Notification/Emergency Phone: 907-793-1236(During normal Business Hours) Notification/Emergency Phone: 907-659-2714(Outside normal Business Hours) Page 9 Version 1 Sept, 2014 Falls Creek#6 Drilling Procedure Hilcorp Energy Company 9.0 R/U and Preparatory Work 9.1 Set 16"conductor at 60' below ground level. 9.2 Dig out and set impermeable cellar. 9.3 Install Seaboard slip-on 16-3/4" 3M "A" section. Ensure to orient wellhead so that tree will line up with flowline later. 9.4 Level pad and ensure enough room for layout of rig footprint and R/U. 9.5 Layout Herculite on pad to extend beyond footprint of rig. 9.6 R/U Saxon Rig# 147, spot service company shacks, spot& R/U company man&toolpusher offices. 9.7 Mud loggers are NOT required on the surface hole section, but can be R/U if deemed necessary to help select surface casing point. 9.8 After rig equipment has been spotted, R/U handi-berm containment system around footprint of rig. 9.9 Mix mud for 12-1/4"hole section. 9.10 Set test plug in wellhead prior to N/U conductor riser to ensure nothing can fall into the wellbore if it is accidentally dropped. 9.11 Install 5-1/2" liners in mud pumps. • TSM 1000 mud pumps are rated at 3633 psi (85%)/333 gpm(100%)with 5-1/2" liners. Page 10 Version 1 Sept,2014 , li Falls Creek#6 Drilling Procedure Hilcorp Energy,Company 10.0 N/U 21-1/4" 2M Diverter System 10.1 N/U 21-1/4" Hydril MSP 2M diverter System./ • N/U 16-3/4" 3M x 21-1/4" 2M DSA(Hilcorp) on 16-3/4" 3M wellhead. • N/U 21-1/4" diverter"T". • Knife gate, 16" diverter line. • Ensure diverter R/U complies with AOGCC reg 20.AAC.25.035(C). / 2) 3,.° Ob.—, ') 10.2 Function test diverter. Ensure that the knife gate and annular are operated on the same circuit so that knife gate opens prior to annular closure. 10.3 Ensure to set up a clearly marked"warning zone" is established on each side and ahead of the vent line tip. "Warning Zone"must include: • A prohibition on vehicle parking • A prohibition on ignition sources or running equipment • A prohibition on staged equipment or materials • Restriction of traffic to essential foot or vehicle traffic only. 10.4 Set 15.375" ID wearbushing in wellhead. Page 11 Version 1 Sept, 2014 Falls Creek#6 El Drilling Procedure Hilcorp Energy Company 10.5 Rig & Diverter Orientation on Falls Creek pad: VALVE ..4*46.11 �. / : BUILDING ,�G� COMPRE S0e:: BLDG ,� C.`1 :3f • o°��Pfo FALLS CREEK •� PRODUCTION PAD c VgP9�N , 1 •� • �/ d)/F A S /2"› ---) CREL FALLS • FALLS N 1 7' CREEK CREEK • FCR 8 � '.� N0.3 NO. 5 • � N 2269431.908i j$ o E 239828.387. ,i„ ELEV.248.93 is 1 , 4, 1\ rte. . Ilk ;1 ,141. `,, 4, • r W — e. ,., .. \f( \'', \' .1'. . FALLS CREEK NO. 6 .• �T AS-STAKED NAD27 ASP ZONE 4 FOREST N:2269393.2 E:239932.3 Page 12 Version 1 Sept, 2014 Falls Creek#6 ii Drilling Procedure Hilcorp Energy Company 11.0 Drill 12-1/4" Hole Section 11.1 P/U 12-1/4" directional drilling assy: • Ensure BHA components have been inspected previously. • Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. • Ensure TF offset is measured accurately and entered correctly into the MWD software. ' • Ensure Gyro MWD is R/U and operational. Be sure to run a UBHO sub so that wireline orientation is possible if necessary. • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. • Workstring will be 4.5" 16.6# S-135 CDS40. 11.2 12-1/4" BHA (No LWD planned in surface hole): COMPONENT DATA Item OD ID Gauge Weight Top Length Cumulative Description Serial Number # (in) (in) (in) (lbpt) Connection (h) Length (ft) MI HDBS FX56M PDC 12.200 2.750 12.250 378.15 B 6-5/8'REG 1.00 1.00 © 8"SperryDrill Lobe 4/5-5.3 stg - 8.000 5.000 IIIII 121.08 B 6-58"REG 28.99 IllEXM - Stabilizer -__ 11.500 _--- © Non Mag Stabilizer 8.000 2.813 12.125 150.12 B 6-58"REG 6.00 35.99 ME 8"DM Collar(Directional) 8.000 3.500 147.40 B 6-58"REG 920 45.19 © 8"TM-HOC(puller) 8.150 4.000 145.20 B 6-58"REG 15.77 60.96 11131 Non Mag Flex Drill Collar 8.000 3.000 147.22 B 6-58"REG 30.00 90.96 MI Non Mag Flex Drill Collar 8.000 3.000 147.22 B 6-58'REG 30.00 120.96 azX-08-5/8 Reg Pin X 4-1/2"IF Box 8.000 2.813 150.12 B 4-1/2'IF 3.50 124.46 Km 6-314'Non Mag Flex Drill Collar 6.750 2.750 10171 B 4-112'IF 30.00 154.46 10 6-3/4'Non Mag Flex Orill Collar 6.750 2.750 101.71 B 4-1/2'IF 30.00 184.46 En X-O 4-1/2'IF Pin X 4-1/T CDS 40 Box 6.500 2.750 92.85 B 4.5'CDS 40 2.75 187.21 ® 6 joints 4-1/2'CDS 40 HWDP 4.500 2.500 37.47 180.00 367.21 ® X-O 4-1/2'CDS 40 Pin X 4-1/2'IF Box 6.500 2.750 92.85 B 4-112'IF 2.75 369.96 m Weatherford 6-1/4'Hyd Jar 111111111.11 6.250 2.250 _ 91.01 B 4-112'IF 30.00 399.96 ® X-O 4-112"IF Pin X 4-1!2"CDS 40 Box 6.500 2.750 92.85 B 4.5"CDS 40 2.75 402.71 in 19Joints 4-1/TCDS 40HWDP 111111111111 4.500 2.500 -Eal_ 570.00 Total:. 972.71 BIT DATA Bit Number Nozzles :9x13 Bit Size (in) : 12.250 TFA (in2) :1.1666 Manufacturer Dull Grade In . Model Dull Grade Out Serial Number .• MOTOR DATA Motor Number : 2 Bend (deg) : 1.15 00 (in) : 8.000 Nozzles (32nd) : 0.0 Manufacturer : Sperry Drilling Avg Diff Press . Model SperryDriG Cumul Cir His . Serial Number . Page 13 Version 1 Sept,2014 Falls Creek#6 Drilling Procedure Hilcorp Energy Company 11.3 Primary Bit: 12-1/4" (311MM) QHC1GRC PRODUCT SPECIFICATIONS IARC Code 117W ' 'l► �► Total Tooth Count 67 Gage Row Tooth Count 39 Journal Angle 33° Offset(116") 6 Jet Nozzle Types Standard 83244 Extended 302447 1111 Center Jet (If Center Jetted)501813 T.J.Connection 6-518"(API Reg.) Recommended Make-Up Torques 28000/32000 Ft•Ibs. Bit Weight(Boxed) 250 Lbs.(113 Kg.) Bit Breaker (Mat_#ILegacy#I) 515353/506463 '4 PRODUCT FEATURES • Nevi patented Diamondm Claw!tooth bit design. +r*w r ▪ Tungsten carbide'surf inserts in gage teeth for added gage protection. • Newly formulated,proprietary hardfacing on cutting structure and gage maximizes carbide and diamond volume for ultimate wear e „ +•' resistance. Y* . High-speed bearing designed for high rpm and high-energy 4111 applications. . Innovative mechanical pressure compensating system provides reliable pressure equalization and relief for maximum bearing and seal life. • Raised tungsten carbide inserts and proprietary hardfacing provides maximum arm protection in abrasive and directional applications while minimizing drill string torque. . QuadPackt Plus Series incorporates its successful"longevity" features and patented engineered hydraulics system for optimal cleaning efficiency. • Center jet feature to prevent bit balling problems Material#622394 *Calculations based on recommendations from API and tool joint manufacturers. O 2012 Halliburton.All rights reserved.Sales of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale. Page 14 Version 1 Sept, 2014 Falls Creek#6 Drilling Procedure Hilcorp EnergY CernrenY 11.4 4-1/2" Workstring & HWDP will come from Saxon. Jars will come from Weatherford. 11.5 Begin drilling out from 16"conductor at reduced flow rates to avoid broaching the conductor. 11.6 Drill 12-1/4"hole section to 3,500' MD. Confirm this setting depth with the geologist and Drilling Engineer while drilling the well. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Pump at 500 - 550 gpm. Ensure shaker screens are set up to handle this flowrate. • Utilize Inlet experience to drill through coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team. • Keep swab and surge pressures low when tripping. • Make wiper trips every 500' or every couple days unless hole conditions dictate otherwise. • Ensure shale shakers are functioning properly. Check for holes in screens on connections. • Adjust MW as necessary to maintain hole stability. • TD the hole section in a good shale btwn 3500' MD and 3550' MD. • • Take MWD surveys every stand drilled (60' intervals). • 11.7 12-1/4"hole mud program summary: Weighting material to be used for the hole section will be barite. Additional barite will be on location to weight up the active system (1)ppg above highest anticipated MW. We will start with a simple gel+ FW spud mud at 8.8 ppg. ✓ Pason PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. System Type: 8.8—9.5 ppg Pre-Hydrated Aquagel/freshwater spud mud Properties: Depths Density' Viscosity Plastic Viscosity Yield Point API FL LGS 80-3500' • 8.8—9.5• 85-150 20-40 25-45 <10 <15% System Formulation: M-1 Gel + FW spud mud Product Concentration Fresh Water 0.905 bbl M-I Gel Export 20 ppb M-I Wate As needed Soda Ash 0.5 ppb Caustic Soda 0.1 ppb Busan 1060 0.04ppb Page 15 Version 1 Sept, 2014 Falls Creek#6 II Drilling Procedure Hilcorp Eng Company 11.8 At TD; pump sweeps, CBU, and pull a wiper trip back to the 16" conductor shoe. 11.9 TOH with the drilling assy, handle BHA as appropriate. 11.10 No open hole logging program planned for Falls Creek#6 surface hole. / Page 16 Version 1 Sept, 2014 v Falls Creek#6 Drilling Procedure Hilcorp Energy Company 12.0 Run 9-5/8" Surface Casing 12.1 R/U and pull 15.375"wearbushing. 12.2 R/U Weatherford 9-5/8" casing running equipment. • Ensure 9-5/8" BTC x CDS 40 XO on rig floor and M/U to FOSV. • R/U fill-up line to fill casing while running. • Ensure all casing has been drifted on the location prior to running. • Be sure to count the total # of joints on the location before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/vendor&model info. 12.3 P/U shoe joint, visually verify no debris inside joint. 12.4 Continue M/U &thread locking shoe track assy consisting of: • (1) Shoe joint w/float shoe bucked on (thread locked). • (1)Joint with coupling thread locked. • (1)Joint with float collar bucked on pin end&thread locked. • Install (2) centralizers on shoe joint over a stop collar. 10' from each end. • Install (1)centralizer, mid tube on thread locked joint and on FC joint. • Ensure proper operation of float equipment. 12.5 Continue running 9-5/8" surface casing • Fill casing while running using fill up line on rig floor. • Use"API Modified"thread compound. Dope pin end only w/paint brush. • M/U connections to the base of the triangle stamped on the pin end. Note M/U torque values required to achieve this position. • After making up several connections,use the torque required to M/U to base of triangle as the M/U torque and continue running string. • Install (1) centralizer every other joint to 300'. Do not run any centralizers above 300' in the event a top out job is needed. • Utilize a collar clamp until weight is sufficient to keep slips set properly. 9-5/8" BTC Estimated M/U Torque Casing OD Est Torque to Reach Triangle Base 9-5/8" 9,630 ft-lbs Page 17 Version 1 Sept,2014 Falls Creek#6 Drilling Procedure Hilcorp Energy Company Tenaris Casing and Tubing Performance Data Choose pipe size,wall thickness and steel grade to view API connection options and performance data. Size 110 Wall 0 Grade-El Connection -0 Unit _0 Pipe Body Data GEOMETRY •i Nominal OD 9.625 in Wall Thickness 0.395 in API Drift Diameter 8.679 in Nominal Weight 40.00 lbs/ft Nominal ID 8.835 in Alternate Drift Diameter 8.75 in I Plain End Weight 38.97Ibsift Nominal Cross Section 11.454 sq in PERFORMANCE Steel Grade L80 Minimum Yield 80,000 psi Minimum Ultimate 95,000 psi Body Yield Strength 916,000 lbs Internal Yield Pressure 5,750 psi Collapse Pressure 3,080 psi Connection Data GEOMETRY Regular OD 10.625 in Threads Per Inch 5 Make-Up Thread Tums 1 PERFORMANCE Steel Grade L80 Minimum Yield 80,000 psi rvlinimum Ultimate 95,000 psi Joint Strength 947,000 lbs Internal Pressure 5,750 psi Resistance TenarisHydril Premium Connections Print I Contact Us Ver 8.6 12.6 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 12.7 Slow in and out of slips. 12.8 P/U casing hanger joint and M/U to string. Casing hanger joint will come out to the rig with the landing joint already M/U. Position the shoe as close to TD as possible. Strap the landing joint while it is on the deck and mark the joint at (1) ft intervals to use as a reference when landing the hanger. 12.9 Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. Page 18 Version 1 Sept, 2014 Falls Creek#6 14 Drilling Procedure Hilcorp Energy Company 12.10 R/U circulating equipment and circulate the greater of 1 x casing capacity or 1 x OH volume. Elevate the hanger offseat to avoid plugging the flutes. Stage up pump slowly and monitor losses closely while circulating. 12.11 After circulating, lower string and land hanger in wellhead again. Page 19 Version 1 Sept, 2014 i Falls Creek#6 Drilling Procedure Hilcorp Energy Company 13.0 Cement 9-5/8" Surface Casing 13.1 Hold a pre job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud& water can be delivered to the cmt unit at acceptable rates. • How to handle cmt returns at surface. • Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. • Positions and expectations of personnel involved with the cmt operation. 13.2 Document efficiency of all possible displacement pumps prior to cement job 13.3 R/U cmt head(if not already done so). Ensure top and bottom plugs have been loaded correctly. 13.4 Pump 5 bbls 10 ppg spacer. Test surface cmt lines. 13.5 Pump remaining 35 bbls 10 ppg spacer. 13.6 Drop bottom plug. Mix and pump cmt per below recipe. 13.7 Cement volume based on annular volume+ 50%open hole excess. Job will consist of lead& tail, TOC brought to surface. Estimated Total Cement Volume: Section: Calculation: Vol (BBLS) Vol (ft3) LEAD: 80' x .129 bpf= 10.3 57.8 16" Conductor x 9-5/8" casing annulus: LEAD: (3000' —80') x .0558 bpf x 1.5 = 244.4 1372 12-1/4" OH x 9-5/8" Casing annulus: Total LEAD: 254.7 bbl 1430 ft3 L77f s TAIL: (3500'-3000') x .0558 bpf x 1.5 = 50 282 12-1/4" OH x 9-5/8" Casing annulus: TAIL: 90 x .096 bpf = 8.7 48.8 9-5/8" Shoe track: Total TAIL: 58.7 bbl 331 ft3 Page 20 Version 1 Sept, 2014 Falls Creek#6 Drilling Procedure Hilcorp Energy Company Cement Slurry Design: Lead Slurry (3000' MD to surface) Tail Slurry(3500'to 3000' MD) System Extended Conventional Density 12.5 lb/gal 15.2 lb/gal Yield 2.13 ft3/sk 1.25 ft3/sk ✓ Mixed 12.02 gal/sk 5.7 gal/sk Water Mixed Fluid 12.03 gal/sk 5.71 gal/sk Code Description Concentration Code Description Concentration Type1 Cement 94 lb/sk WBWOB Type1 Cement 94 lb/sk WBWOB Static Free De-Foamer 0.005 lbs/sk Static Free De-Foamer 0.005 lbs/sk CaCI Accelerator 2% bwoc CaCI Accelerator .25% bwoc Additives CD-32 Dispersant 0.4% bwoc CD-32 Dispersant 0.5% bwoc FL-52 Fluid Loss Add 0.3% bwoc FL-52 Fluid Loss Add 0.2%bwoc FP-6L De-Foamer 1 gal/100 sk FP-6L De-Foamer 1 gal/100 sk Na Extender 2% bwoc Metasillicate 13.8 Attempt to reciprocate casing during cement pumping if hole conditions allow. Keep the hanger elevated above the wellhead while working. If the hole gets "sticky", land the hanger on seat and continue with the cement job. 13.9 After pumping cement, drop top plug and displace cement with 9.5 ppg Kla-shield. 13.10 Ensure cement unit is used to displace cmt so that volume tracking is more accurate. 13.11 Displacement calculation: 3400' x .0758 bpf=257.7 bbls 13.12 Monitor returns closely while displacing cement. Adjust pump rate if necessary. If hanger flutes become plugged, open wellhead side outlet in cellar and take returns to cellar. Be prepared to pump out fluid from cellar. Have some sx of sugar available to retard setting of cement. 13.13 Do not overdisplace by more than V2 shoe track volume. Total volume in shoe track is 8.7 bbls. 13.14 Be prepared for cement returns to surface. If cmt returns are not observed to surface, be prepared to run a temp log btwn 6— 18 hours after CIP. 13.15 Be prepared with small OD top out tubing in the event a top out job is required. The AOGCC will require us to run steel pipe through the hanger flutes. The ID of the flutes is 1.5". Page 21 Version 1 Sept, 2014 Falls Creek#6 ii Drilling Procedure Hilcorp EnergY Co 13.16 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold, pressure up string to final circulating pressure and hold until cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating pressure if pressure must be held. 13.17 R/D cement equipment. Flush out wellhead with FW. 13.18 Back out and L/D landing joint. Flush out wellhead with FW. 13.19 M/U pack-off running tool and pack-off to bottom of Landing joint. Set casing hanger packoff. Run in lock downs and inject plastic packing element. 13.20 Lay down landing joint and pack-off running tool. Ensure to report the following on wellez: • Pre flush type,volume(bbls)&weight(ppg) • Cement slurry type, lead or tail,volume&weight • Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration a. Pump rate while displacing,note whether displacement by pump truck or mud pumps,weight&type of displacing fluid b. Note if casing is reciprocated or rotated during the job c. Calculated volume of displacement, actual displacement volume, whether plug bumped&bump pressure, do floats hold d. Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure e. Note if pre flush or cement returns at surface&volume f. Note time cement in place g. Note calculated top of cement h. Add any comments which would describe the success or problems during the cement job Send final "As-Run" casing tally & casing and cement report to lkeller@hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. Page 22 Version 1 Sept, 2014 Falls Creek#6 Drilling Procedure Hilcorp Energy Company 14.0 BOP N/U and Test 14.1 N/D the conductor flow riser. 14.2 N/U Seaboard multi-bowl wellhead assy. Install packoff 9-5/8"P-seals. Test to 3000 psi. 14.3 N/U 11"x 5M T3-Energy BOP as follows: • BOP configuration from Top down: 11"x 5M T3-Energy annular BOP/11"x 5M T3-Energy Model 6011i double ram/11"x 5M mud cross/11"x 5M T3-Energy Model 6011i single ram • Double ram should be dressed with 2-7/8 x 5-1/2" VBRs p top cavity, blind ram in btm cavity. • Single ram should be dressed with 2-7/8 x 5-1/2" VBRs • N/U bell nipple, install flowline. • Install (2)manual valves&a check valve on kill side of mud cross. • Install (1)manual valve on choke side of mud cross. Install an HCR outside of the manual valve. 14.4 Run 4-1/2"BOP test assy, land out test plug(if not installed previously). • Test BOP to 250/3500 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min. • Ensure to leave "B" section side outlet valves open during BOP testing so pressure does not build up beneath the test plug. 14.5 R/D BOP test assy. 14.6 Dump and clean mud pits, send spud mud to G&I pad for injection. 14.7 Mix 9.5 ppg Kla-Shield mud system. 14.8 R/U mud loggers for production hole section. 14.9 Set 10" ID wearbushing in wellhead. 14.10 Rack back as much 4-1/2"DP in derrick as possible to be used while drilling the hole section. 14.11 Keep 5-1/2" liners in mud pumps. Page 23 Version 1 Sept, 2014 Falls Creek#6 Drilling Procedure Hilcorp Energy Company 15.0 Drill 8-1/2" Hole Section 15.1 P/U 8-1/2" directional BHA. 15.2 Ensure BHA components have been inspected previously. 15.3 Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. 15.4 TF offset is measured accurately and entered correctly into the MWD software. 15.5 Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. 15.6 Workstring will be 4.5" 16.6# S-135 CDS40. Page 24 Version 1 Sept,2014 Falls Creek#6 Drilling Procedure Hilcorp Energy Company 15.7 8-1/2" BHA (Includes GR+Res+Den/Neu LWD components): _... ° . ..a. Cumulative ' ength '(H):: 1 HDBS-FX65D 8.400 2.500 8.500 172.13 P 4-112'REG 1.00 1.00 2 r SperryDrill Lobe 7/8-6.0 sig 7.000 4.952 93.13 B 4-112"IF 27.38 28.38 Stabilizer 7.750 3 Non Mag Float Sub 6.750 2.750 101.71 B 4-112"IF 3.00 31.38 4 Integral Blade Stabilizer(NM) 6.750 2.813 8.375 100.77 B 4-112"IF 5.00 36.38 5 6 314"DM(Directional) / 6.750 3.125 103.40 B 4-1i2"IF 9.20 45.5E 6 6 314"DGR(Gamma) 7 5.750 1.920 97.80 B 4-112"IF 4.55 50.14 7 6 314"EWR-P4 (Resistivity) / 6.750 2.000 104.30 B 4-112"IF 12.10 62.24 B 6 314'HCIM ;Processor} 6.750 1.920 101.70 B 4-112"IF 4.97 67.21 9 6 314"ALD Colin 175C 30KSI 6.750 1.92c 8.250 104 30 P NC 50 14.54 81.75 Stabilizer 8.250 10 6 3,4'CTN Collar 175C 30KS1 8.750 1.905 102.30 B NC 50 11.84 93.59 11 6 314"TM-HOC(Puller) 5.900 3.250 103.60 B 4-112"if 15.59 109.18 12 6-314"Non Mag Flex Drill Collar 6.750 2.813 100.77 B 4-112'IF 30.00 139.18 13 6-314"Non Mag Flex Drill Collar 6.750 2.813 10077 B 4-112-IF 30.00 189.18 14 X-0 4-112"CDS 40 Box X 4-112"IF Fir 6.500 2.750 92.85 B 4.5 CDS 40 2.75 171.93 15 6 Joints 4-1;2"CDS 40 HWDP 4.500 2.500 37.47 180.00 351.93 16 X-0 4-112"IF Box X 4-112"CDS 40 Pin 6.500 2.750 92.85 B 4-112"IF 2.75 354.58 17 Weatherford 6-114"Jars 6.250 2.250 91.01 B 4-112"IF 30.00 3.84.68 18 X-0 4-112"IF Pin X 4-1i2"CDS 40 Box 6.500 2.750 92.85 B 4.5"CDS 40 2.75 387.43 19 19 Joints 4-112"CDS 40 HWDP 4.500 2.500 37.47 570.00 957.43 y�ex„ � � 957.43 BIT DATA Bit Number Nozzles :5x13 Bit Size (in) - 8 500 TFA (int} :0.8481 Manufacturer Dull Grade In . Model Dull Grade Out .• Serial Number Page 25 Version 1 Sept, 2014 Falls Creek#6 Drilling Procedure Hilcorp Energy Company 15.8 Primary Bit: 8-1/2" (216mm) MM65M PRODUCT SPECIFICATIONS Cutter Type SelectCutter 1ADC Code M324 Body Type MATRIX Total Cutter Count 41 Cutter Distribution JIM D.-W. Face 1 29 Gauge 5 0 ) „ Up Drill 6 0 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 of Replaceable Ports(Size) 0 ^ Junk Slot Area(sq in) 14.81 ' Normalized Face Volume 42.13.10 API Connection 4-1/2 REG.PIN Recommended Make-Up Torque* 12.461—17.766 Ft•lbs. Nominal Dimensions•' *4. Make-Up Face to Nose 10.73 in-273 mm Gauge Length 25 in-64 mm Sleeve Length 0 in-0 mm A Asa Shank Diameter 6 in-152 mm Break Out Plate(MaL#fLegacy#) 181954144040 Approximate Shipping Weight 160Lbs.-73Kg, SPECIAL FEATURES 1/32"Relieved Gage.Combination BackreamlUp-Drill Cutters, Secondary Cutting Element-"R"Feature.TSP Gage Material#803275 `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 Section A.8-1. "Design dimensions arc nominal and may vary slightly on manufactured product_Halliburton Drill Bits and Services models arc continuously reviewed and refined. Product specifications may change without notice. t.7 2013 Halliburton.All rights reserved.Sales of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale. Page 26 Version 1 Sept, 2014 Falls Creek#6 Drilling Procedure Hilcorp Energy Company 15.9 8-1/2" hole section mud program summary: Weighting material to be used for the hole section will be salt and calcium carbonate. Additional calcium carbonate will be on location to weight up the active system (1)ppg above highest anticipated MW. NOTE: Only use the "Black Products" & corrosion inhibitors if absolutely necessary. These products can leave behind a damaging skin that affects productivity of the well. Pason PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. System Type: 9.5 ppg Kla-Shield fresh water based drilling fluid with 6% KCl. Properties: Depths (Density Plastic Viscosity Yield Point Chlorides API FL pH 3500'-9,558'• `,,� 9.5 10-20 15-25 60,000—70,000 <8 9.0- 10 i System Formulation: M-I Swaco Kla-Shield with 6% KCI Product Concentration/Function Water Base Fluid Busan 1060 0.4 ppb Biocide Soda Ash 0.25 ppb PH/Hardness Control Flowzan 1.0 ppb Viscosifier/Rheology KCL 21.8 ppb weight/inhibition NaCI Salt 20.0ppb weight/inhibition Poly Pac Sup UL 0.75 ppb API Fluid Loss EMI-2009 2-3%v/v Clay/Shale inhibitor Safe-Carb 40 If needed for weight increase over Conqor 404 9.0ppg Asphasol Supreme Corrosion Mitigation Sack Black 4ppb Shale/Coal Stabilizer 3ppb-Gilsonite Shale/Coal Stabilizer 15.10 TIH w/ 8-1/2" directional assy to TOC. Shallow test MWD and LWD on trip in. Note depth TOC tagged on AM report. 15.11 R/U and test casing t 29001/30 min. Ensure to record volume /pressure and plot on FIT graph. AOGCC reg is % of burst= 5750/2 =2875-2900 psi 15.12 Drill out shoe track and 20' of new formation. Page 27 Version 1 Sept, 2014 Falls Creek#6 Drilling Procedure Hilcorp Enargy Company 15.13 CBU and condition mud for FIT. 15.14 Conduct FIT to 12 pp W. Note: Offset field test data predicts frac gradient at the 9-5/8"shoe to be btwn 17- 18 ppg EMW. A 12 ppg FIT results in a 2.5 ppg kick margin while drilling with the planned MW of 9.5 ppg• 15.15 Drill 8-1/2"hole section to 9,558' MD / 8,690' TVD. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Pump at 400 - 450 gpm. Ensure shaker screens are set up to handle this flowrate. • Utilize inlet experience to drill through coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team, try to avoid sliding through coal seams. Work through coal seams once drilled. • Keep swab and surge pressures low when tripping. • Make wiper trips every 500' or every couple days unless hole conditions dictate otherwise. • Ensure shale shakers are functioning properly. Check for holes in screens on connections. • Adjust MW as necessary to maintain hole stability. Keep HTHP fluid loss < 10. • Take MWD surveys every other stand drld. Surveys can be taken more frequently if deemed necessary. • Mud loggers: Take samples every 30 ft, with 20 ft samples in zones of interest. Two sets of cuttings required, gas chromatograph,pixler plots. 15.16 At TD; pump sweeps, CBU, and pull a wiper trip back to the 9-5/8" shoe. 15.17 TOH with the drilling assy, stand back BHA if possible. Drop a drift on the last trip out of the hole in preparation for running the liner. 15.18 R/U and run OH wireline logs consisting of: • Dipole Sonic 15.19 Monitor the well at all times on the trip tank while logging. 15.20 After logging objectives accomplished, pick up a wiper trip BHA and make another run to TD. Circ B/U at TD and TOH. Rack back DP, handle BHA as appropriate. Page 28 Version 1 Sept, 2014 Falls Creek#6 Drilling Procedure Hilcorp Energy Company 16.0 Run 5-1/2" Production Casing 16.1. R/U 5-1/2"casing running equipment. • Ensure 5-1/2"DWC/C x CDS 40 crossover on rig floor and M/U to FOSV. • R/U fill up line to fill casing while running. • Ensure to R/U Tesco or Weatherford CRT so that string can be rotated if necessary while running. • Ensure all casing has been drifted on the deck prior to running. • Be sure to count the total #of joints on the deck before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/vendor&model info. 16.2. P/U shoe joint, visually verify no debris inside joint. 16.3. Continue M/U&thread locking shoe track assy consisting of: • (1) Shoe joint w/ shoe bucked on&threadlocked (coupling also thread locked). Install (2) solid body centralizers on shoe joint prior to bucking on float shoe. The centralizers should be held in place 10' from each end via stop rings on either side. • (1) Thread locked joint(coupling thread locked). Install one coupling on thread locked joint and leave it free floating on the joint. • (1) Joint with float collar bucked on pin end &threadlocked (coupling also thread locked). Install (1) solid body centralizer on float collar joint prior to bucking on float collar. • Ensure proper operation of float shoe and float collar prior to running in the hole. 16.4. Continue running 5-1/2"prod casing. • Fill casing while running using fill up line on rig floor. • Use "Best 0 Life 2000"thread compound. Dope pin end only w/paint brush. • Installsolid body centralizers on every joint to 5,400 MD. Every other joint to 3800'. None above 3800'. Leave the centralizers free floating. • Utilize a collar clamp until weight is sufficient to keep slips set properly. 5-1/2" CDC M/U torques Casing OD Minimum Maximum Yield Torque 5.5" 8,500 ft-lbs 10,500 ft-lbs 13,000 ft-lbs Page 29 Version 1 Sept,2014 Falls Creek#6 11 Drilling Procedure Hilcorp Energy Company ID U. S. Steel Tubular Products 5.5 17/1).304 P110 HC USS-CDCTM ...r . Air. . . i MECHANICAL PROPERTIES Pipe USS.CDC", Minimum Yield Strength 110,000 -, psi Masirnum Yield Strength 140,000 — psi MWornum Tensile Strength 125,000 -• psi DIMENSIONS Pips U8*CDC'a Outside Diameter 5.500 8,.050 In. Wall Thickness 0.304 — in. Inside Diameter 4.892 4.842 in, Standard Drift 4.767 4.767 in, Alternate Drift .. — m. Coupling Length -- 9 250 m. Nominal Linear Weight,T&C 17.00 teat oisin End Weight 1689 — the SECTION AREA PIp. us8°CDe" > `ii ,. : ,...4 1a #x4.,4 Critiosi Area -- 4 962 sq.in. Joint Efficiency -- 100.0 % , ,,, mnmm >ee W,w. .vuk'A,aeeee Minimum Collapse Pressure 8,730 8,730 psi External Pressure — 6,984 psi Minimum Internal Yield Pressure 10.640 10,600 psi Minimum Pipe 9odp Yield Strength 545 — 1 lex Joint Strength - 568,E 1000 ilia Compression Rating -- 340,800 les Relevance Larrpth •- 22,275 8 Mai!mum Unisxial Send Rem 57.2 degt100 it Melas44 Loss — 4.63 in. Minimum Make-Up Torque — 8,500 ft-La Maximum Make-Llp Torque -- '°0.500 It-Da Connection Yield Torque -- 13,000 R-eas Verification of connection shoulder noosed Twoicel shoulder range 16.5. M/U casing hanger joint to string. Casing hanger joint will come out to the rig with the landing joint already M/U. Position the shoe approx 10—20' above TD. Strap the landing joint while it is on the deck and mark the joint at(1) ft intervals to use as a reference when landing the hanger. Page 30 Version 1 Sept,2014 Falls Creek#6 Drilling Procedure Hilcorp 1"1 Energy Company 16.6. Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. 16.7. R/U circulating equipment and circulate the greater of 1 x casing capacity or 1 x OH volume. Elevate the hanger offseat (slightly) to avoid plugging the flutes. Stage up pump slowly and monitor losses closely while circulating. 16.8. After circulating, lower string and land hanger in wellhead again. Page 31 Version 1 Sept, 2014 Falls Creek#6 Drilling Procedure Hilcorp Energy Company 17.0 Cement 5-1/2" Production Casing 17.1. Hold a pre job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud& water can be delivered to the cmt unit at acceptable rates. • How to handle cmt returns at surface,regardless of how unlikely it is that this should occur. • Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. • Positions and expectations of personnel involved with the cmt operation. • Document efficiency of all possible displacement pumps prior to cement job. 17.2. Attempt to reciprocate the casing during cmt operations. 17.3. Pump 5 bbls 10 ppg SealBond spacer. 17.4. Test surface cmt lines to 4500 psi. 17.5. Pump remaining 15 bbls 12 ppg SealBond spacer. 17.6. Mix and pump lead and tail cmt per below recipe. Ensure cmt is pumped at designed weight. Job is designed to pump 30% OH excess. 3° o Section: Calculation: (BBLS) Vol (ft3) 9-5/8" x 5-1/2" Overlap(Lead): 500' x 0.046 = 23 129 8-1/2" OH x 5-1/2"Liner(Lead): (6,350-3,500') x 0.0408 x 1.3 = 151.1 848.4 8-1/2" OH x 5-1/2" Liner(Tail): (9,558' -6,350')x 0.0408 x1.3 = 170.1 955.1 Shoe Track(Tail): 90' x 0.023 = 2.1 11.8 Total Volume (Lead): 174.1 bbls 977.6 ft3 C.56.5'• Total Volume (Tail): 172.2 bbls 966.9 ft3 71 t- Page 32 Version 1 Sept, 2014 Falls Creek#6 Drilling Procedure Hilcorp Energy Company Lead Slurry (6350' to 3500') Tail Slurry (9558' to 6350' MD) System Extended Conventional Density 13.5 lb/gal 15.2 lb/gal Yield 1.82 ft3/sk 1.25 ft3/sk Mixed Water 9.21 gal/sk 5.7 gal/sk Mixed Fluid 9.22 gal/sk 5.71 gal/sk Code Description Concentration Code Description Concentration Class G Cement 94 lb/sk Type1 Cement 94 Ib/sk WBWOB WBWOB BA-90 Low den. additive 10% bwoc Static Free De-Foamer 0.005 lbs/sk BA-56 Gas Migration 2.5% bwoc R-3 Retarder 0.9% bwoc CD-32 Dispersant 0.4% bwoc CD-32 Dispersant 0.6% bwoc Additives Free water ASA-301 control 0.1% bwoc FP-6L De-Foamer 1 gal/100 sk FP-6L De-Foamer 1 gal/100 sk BA-10A Bonding 1% bwoc agent Metasillicate Extender 0.5% bwoc Metasillicate Extender 0.5% bwoc Static Free De-Foamer 0.005 lbs/sk 17.7. Drop DP dart and displace with 6% KCl. 9400' x .023 = 216.2 bbls 17.8. Do not overdisplace by more than V2 shoe track. Shoe track volume is 1.7 bbls. 17.9. Bleed pressure to zero to check float equipment. 17.10. Pressure up again to 3500 psi and hold for 30 min to test production bore. Page 33 Version 1 Sept, 2014 , . Falls Creek#6 ti Drilling Procedure Hilcorp Energy Company Ensure to report the following on wellez: • Pre flush type,volume(bbls)&weight(ppg) • Cement slurry type, lead or tail,volume&weight • Pump rate while mixing,bpm,note any shutdown during mixing operations with a duration i. Pump rate while displacing,note whether displacement by pump truck or mud pumps,weight&type of displacing fluid j. Note if casing is reciprocated or rotated during the job k. Calculated volume of displacement, actual displacement volume,whether plug bumped &bump pressure, do floats hold 1. Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure m. Note if pre flush or cement returns at surface&volume n. Note time cement in place o. Note calculated top of cement p. Add any comments which would describe the success or problems during the cement job Send final "As-Run" casing tally & casing and cement report to lkeller@hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. Page 34 Version 1 Sept, 2014 Falls Creek#6 Drilling Procedure Hileorp Energy Company 18.0 RDMO 18.1 Install back pressure valve in hanger neck. N/D BOP. 18.2 Install &test production tree. 18.3 RDMO Saxon rig#147 18.4 After rig has departed, pull BPV and run CBL to determine TOC behind 5-1/2"production casing. Send the CBL to the AOGCC for review. c-LA_ t 19.0 Perf and Frac 19.1 A separate sundry will be submitted to the AOGCC that will cover the below operations: • R/U workover rig • Run production tubing/pkr/CIM & SCSSV. • Perforating and flowback. • And hydraulic fracturing or other stimulation that may be necessary to produce the well commercially. Page 35 Version 1 Sept, 2014 8 Falls Creek #6 II Drilling Procedure Hilcorp Energy Company 20.0 BOP Schematic ______---- e_e 1-1 lid 1a1 a fil r 1 f 1 1 P3- Energy • Saxon Rig 147 11"5M . T-3 Erergy BOP Iii iii 1i11M11ii , XS /Z =Eno + Model6711i 74 -I -; � - � iLl — L,' Manual Manual -- — Manual FCR 1 1 .9" Va've Va ve Valve 11111811111 III III Kill ,trf.., �z - 111114 _> y Choke Line :i�'r -+T;, {�.�-� fNil- :f"I,: Line �.� is ' -- — — r f= - _ ��J -iii IILI02�II1 Bei _ Grade Love, MI Br 1411 op ow Spacer spool . 95' 11 5M X 11 5M ti ill fill 1!1 151 — Seaboard-MBS system •'I 4i++ is-i• 15 '%3M X 11 5M - 1 • • ter * r -.1■. . Illtiliei.- 'II1 � r4 _ + s i l 1 -��I " 0 411i 1. 1 8-5(8" la Page 36 Version 1 Sept, 2014 • Falls Creek#6 II Drilling Procedure Hilcorp Energy Company 21.0 Wellhead Schematic Ninilchik Unit New drill system-Seaboard Saxon Rig 147 16 x95/8 x51/2 it. Y., 4:*:--^ a _° inimi Tubing head,Seaboard-S8, 11 5M X 7 1/16 5M, w/2-2 1/16 5M SSO, : I ', t 124 7"P seal bottom i �� 'a °J o ; 1 I '1 c� 1 i 71 • ■iii—i r Casing spool,Seaboard S8, �.4.�;14 ,11J IP 16 3/4 3M X 11 5M, - ' G(:---t-)_ ;1 • w/2-21/165M SSO, i i mg � 0 )of a i•I•. 9 5/8 P seaI bottom a „ � 4 ..-:. -ae oImasIi - -4.1.00hwl Starting head,Seaboard, 167.3M X 16"SOW BTM, II '' w/2-2 1/16 5M SSO J II. 111 _ : -1. 16" 9 5/8" L 5%" Page 37 Version 1 Sept, 2014 Falls Creek#6 Drilling Procedure Hilcorp Energy Company 22.0 Days Vs Depth Days Vs Depth 0 � -FaIIs Creek#6 -Falls Creek#5 2000 4000 z 6000 in8000 10000 12000 0 5 10 15 20 25 30 35 40 Days Page 38 Version 1 Sept, 2014 Falls Creek#6 ii Drilling Procedure Hilcorp Energy Company 23.0 Formation Tops ANTICIPATED FORMATION TOPS&GEOHAZARDS EXPECTED Intersection Points TOP TOP NAME FLUID MD(FT) TVD(FT) TVDSS(FT) Est.Pressure X Y +i Beluga 135 Pos Gas 5461 4,906 -4,716 r 2110 TJonek. GAS 5748 5,159 -4,969 2218 r E T-8 Tight Gas 6566 5,882 -5.692 2529 r T-10 Tight Gas 6885 6.164 -5,974 2651 r T-50 GAS 8229 7,448 -7,2588 3203 r T-60 GAS 8463 7.671 -7,481 3299 238836 2272181 T-65 GAS 8886 8,075 -7,885 r 3472 Total Depth 9528 8,690 -8,500 r 3737 r 238534 r 2272904 Primary Objective =Secondary Objective TARGETRADIUS 100 FT Page 39 Version 1 Sept,2014 Falls Creek#6 Drilling Procedure Hilcorp Energy Company 24.0 Anticipated Drilling Hazards 12-1/4" Hole Section: Lost Circulation: Ensure adequate amounts of LCM are available. Safe-carb 10, 20, 40, 250, & 750. Ensure G-seal, Pecan nut plug, and Mix II are also available for more severe lost returns incidents. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of Safe-carb 10 & 20 to the active system at 1 —2 ppb. Hole Cleaning: Maintain rheology w/gel and gel extender. Sweep hole with gel or flowzan sweeps as necessary. Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. Maintain YP btwn 25 —45 to optimize hole cleaning and control ECD. Wellbore stability: Lithology through this zone is a composite of pebble conglomerate and sand in the upper intervals with intermittent clay matrix. Carbonaceous material and coal may be noted. Gravel sizes that are larger than normal can cause hole-cleaning problems. If encountered, be prepared to increase the viscosity. Excessive quantities of gravel and sand may indicate wellbore instability. Increase properties up to a YP of—50 -—60 lbs/100ft2 to combat this issue. Maintain low flow rates for the intial 200' of drilling to reduce the likelihood of washing out the conductor shoe. To help insure good cement to surface after running the casing, condition the mud to a YP of 25—30 prior to cement operations. Do not lower the YP beyond 25 to avoid trouble with sands that may be found on this well. Have Desco DF, SAPP, and water on hand to ensure the desired rheologies can be achieved. H2S: H2S is not present in this hole section. No abnormal pressures or temperatures are present in this hole section. Page 40 Version 1 Sept,2014 Falls Creek#6 titDrilling Procedure Hilcorp Energy Company 8-1/2" Hole Section: Lost Circulation: Ensure adequate amounts of LCM are available. Safe-carb 10, 20, 40, 250, & 750. Ensure G-seal, Pecan nut plug, and Mix II are also available for more severe lost returns incidents. Monitor fluid volumes to detect any early signs of lost circulation. For minor seepage losses, consider adding small amounts of Safe-carb 10 &20 to the active system at 1 —2 ppb. Hole Cleaning: Maintain rheology w/flowzan. Sweep hole w/20 bbls hi-vis pills as necessary. Optimize solids control equipment to maintain density and minimize sand content. Maintain YP btwn 20 - 30 to optimize hole cleaning and control ECD. Wellbore stability: Maintain 1ppb total of PolyPac Supreme UL to maintain a thin/strong wall cake and keep HTHP filtrate below 9 ml/30 min. Maintain MW as necessary using additions of Barite. Maintain 6 ppb EMI-2009 for shale/clay inhibition. Maintain 4 ppb Asphasol Supreme& 3 ppb Sack Black for Shale/Coal stabilizer. Maintain 6%KC1 in system for shale inhibition. Coal Drilling: The following lessons were learned from extensive experience drilling coal seams in Cook Inlet. The need for good planning and drilling practices is also emphasized as a key component for success. • Keep the drill pipe in tension to prevent a whipping effect which can disturb coal sections. • Use asphalt-type additives to further stabilize coal seams (Asphasol Supreme, Sack Black). • Increase fluid density as required to control a"running coal". • Emphasize good hole cleaning through hydraulics, ROP and system rheology. In the event that sloughing coal is encountered, consider spotting a 30 ppb Asphasol Supreme pill across the coal seam. The pill can be safely "squeezed" into the coal by closing the bag and applying pressure not to exceed the total annular pressure loss. H2S: H2S is not present in this hole section. No abnormal temperatures are present in this hole section. Page 41 Version 1 Sept, 2014 Falls Creek#6 11 Drilling Procedure Hilcorp Energy Company 25.0 Saxon Rig 147 Layout 123'-7" 3€'-C" 55•-6" 30'-C" 2'_1" b - PRE-MIX TANK (TCITAL WI .1R8 RAI cj II ' r I1 ■7t V �'- �C alt IIr1111111111111 I11' .1"I '' I S ''I Ill ll 1 • r 1 '31.1 , ,. 1II,IIIIIII1I111I1 r.r,-i- lkiliffiffil ., 1111111111.111M11111 IIIIIIgI'I�IIIIIGII II _ ., _ � .. ui u■rIn! II It: �I `1 r E IN ''_ .'' —_ AfitD cAs° �HMt�Id11 El I � � = _ �. _ N 1I II AND PUMP it '�I I 1 t I i�1♦ U - �� 1;'24P-'''''''"--7 'a[PFt�iTOR cal° �II111R�111• 11 r.'r rv�!!" +I>•�' t �I IMr�t111rL1'. �Fillf s QIP innnnal� ...,�, ,..,.: 111111IIIIIIIIIIIIINI11INI11IIIIIIIIIIIIIIIIIIIIIIIIIIIIIiII1111III1111111111111III11111N11I111111I111'IIIIIIIIIIIIIINIIulumummn P_I nnInnumgllllllllllllllllllllllllllli EO�llIllIIIIIIIllIlIIllIIlIIIIINII IIII IIIIIIIIIIIIIaI►1MI IIIIIIIIIINI11111IIII1111111111IIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIOI1n111I111 iiii111iri111111111111111111.IIIIIIIIIIIIIIIIlIIIIIIIIIIIII'I°' -- IIIIrm1r1i11 111111I111118l11lIlII�III11IIIIIIIIII111101Illllllln Imminimir. — 1111 II II IIIIIIIIIIIIIIIIIIII61 — -, - V■n °'"°"""'"aI'll I I mwgItIrn,RE I " •�_i—.II 00 -' ... Al IIIIIIIII111I11111 ! poiVER CAMALP,c ..=: IINIII>lI1IIIIIIIIl1IINIIINIIIIIIIIIIIIIIIIIIIIIrnrrlrnnnurr,.•• -- In_— III/1IIII111IIIIIium- Aga 11 IIIIIIIIIIIIINIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIII111111111111III'iI ipipiin I I IIIIIIIIIIIIIIIIIIIIIIIIIIIIIii, IIIIIIIIIIIIII o IIIIIIIIIIIlllI1NIIIIhIIl11111111IIIIIIIllll111IIII11111IIIIIIIIIIIIIIIilINIIIIIUII-Ii ill111111IN 01111111111111111111111111111111111111 HIIIIIIIIlt'h 10 Ill — 1111111111 -- 1-,a un Immr rnm. I , I , ,4 II!U! ii © • °-r.1-1- Ir• •■ IIIIiI100-1011' ■.I p.,.. ►;•alii as amR, 6 L e Q DaGeeNSEIWATER TAI.K(TOp.ROOM 53'_0" 45'-O" • 85'-0" Iirc 85'-5" 170'-4" Page 42 Version 1 Sept,2014 Falls Creek#6 Drilling Procedure Hilcorp Energy Company 26.0 FIT Procedure Formation Integrity Test (FIT) and Leak-Off Test (LOT) Procedures Procedure for FIT: 1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe). 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer(ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1-minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre-determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick tolerance in case well control measures are required. Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. Page 43 Version 1 Sept, 2014 . , Falls Creek#6 11 Drilling Procedure Hilcorp Energy Company 27.0 Choke Manifold Schematic p 1 e ii, i ` 4 e) 1 , 1.�. P 'T .4 Lam.! �e P 1 4; _. 0 ' • I 1 1 .k , m ' ''"ite l (C P 1 I _ i -..... - isk.4,, •:1 VII:. a i i 1 tAprierre•-•/P-', !-.1 / b y io + h1i9 tell f: . 0 s;iii 1U;y IR Iii L i IS II tlA i i L_ L �e 1 ;11 iii[ ��I Page 44 Version 1 Sept, 2014 • Falls Creek#6 Drilling Procedure Hilcorp Energy Company 28.0 Casing Design Information Calculation &Casing Design Factors DATE: 9115/2014 WELL: Falls Creek#6 DESIGN BY:Luke Keller Design Criteria: Hole Size 12-1 4" Mud Density: 8.8 ppc Hole Size 8-12'' Mud Density: 9.5 ppg Hole Size Mud Density: Drilling Mode MASP: 2750 psi(see attached MASP determination&calculation) MASP: Production Mode MASP: 2868 psi(see attached MASP determination&calculation) Collapse Calculation: Section Calculation 1 Normal;^rad'ent external stress?:0.494 a+ )and the casing evacuated for the internal stress c9.Spr5- Casing Section Calculation/Specification 1 2 3 4 Casing OD 9-5/& 5-1124 Top(MD) 0 0 Top(TVD) 0 0 Bottom (MD) 3.500 9.558 Bottom{TVD; 3.289 8.690 Length 3.500 9.558 Weight(ppf) 40 17 Grade L-80 P-110 Connection BTC CDC Weight w/o Bouyancy Factor(lbs) 140,000 162,486 Tension at Top of Section(lbs) 140,000 162,486 Min strength Tension(1000 lbs) 916 545 Worst Case Safety Factor(Tension) 6.54 3.35 Collapse Pressure at bottom (Psi) 1.625 4.293 Collapse Resistance wlo tension(Psi) 3.090 8.730 Worst Case Safety Factor(Collapse) 1.90 2.03 MASP(psi) 2.750 2.868 Minimum Yield (psi) 5.750 ! 10,600 Worst case safety factor(Burst) 2.09 3.70 • Page 45 Version 1 Sept, 2014 Falls Creek#6 Drilling Procedure Hilcorp Energy Company 29.0 8-1/2" Hole Section MASP Maximum Anticipated Surface Pressure Calculation 8-1/2"Hole Section »itch Falls Creek#6 Ninilehik Unit MD ND Planned Top: 3500 3289 Planned TD: 9558 8690 Anticipated Formations and Pressures: Formation ND Est Pressure Oil/Gas/Wet PPG Grad Beluga 135 4,906 2110 Pos Gas 8.3 0.430 Tyonek 5,159 2218 Pos Gas 8.3 0.430 T-8 5,882 2529 GAS 8.3 0.430 T-10 6,164 2651 Tight Gas 8.3 0.430 1-50 7,448 3203 Tight Gas 8.3 0.430 1-60 7,671 3299 GAS 8.3 0.430 1-65 8,075 3472 GAS 8.3 0.430 TD 8,690 3737 ??? 8.3 0.430 Offset Well Mud Densities Well MW range Top(TVD) Bottom(TVD) Date Falls Creek#1 11.6-13.1 3,500 10,000 1960 Falls Creek#2 10.5-11 3,500 6,300 1966 Falls Creek#3 9.4-9.5 3,500 8,400 2003 Falls Creek#4 9-9.5 3,500 6,000 2004 Falls Creek#5 9.5-9.7 / 3,520 9,715 / 2014 Corea Creek#1 9.5-10.9 3,500 9,000 1996 Frances#1 9.5-9.8 3,500 10,000 2013 Assumptions: 1. Fracture gradient at shoe is estimated at 0.936 psi/ft based on field test data. 2, Maximum planned mud density for the 8-1/2"hole section is 9.5 ppg. 3. Calculations assume"Unknown"reservoir contains 100%gas(worst case), 4. Calculations assume full evacuation of wellbore to gas Fracture Pressure at 9-5/8"shoe considering a full column of gas from shoe to surface: 3289(ft)x 0.936(psi/ft)= 3079 psi 3079(psi)-[0.1(psi/ft)'3289(ft))= 2750 • i MASP from pore pressure(unknown gas sand at TD,at 8.4 ppg,encountered while drilling) 8,690{ft)x 0.43(psi/ft)= 3737 psi 3737(psi)-0.1(psi/ft)'8,690(ft) 2868 psi Page 46 Version 1 Sept, 2014 • • Falls Creek#6 Drilling Procedure Hilcorp Energy Company 30.0 Spider Plot (NAD 27) (Governmental Sections) ADL384318 ealb€0 022,S11 S002 NO13W ADL384314 S002 NO12W // : II,( rec.%i' l'-',111.1 i f ADL389737 ADL389737 t 4" / 1.J , --•Tram-re t, .. t•.. •t aC l t t.t,. / Prrin`e ' / i . // .. . FRANCES , 2 BHL r -, • r . / NINILCHIK2 •Texl.188 Falls I AM L•COSO3 Creek ..... ,. .., Falls : / i „,„,,,, , 1 , / ease Creek PA 6 TPH ,, _ 6 yTrar-ze 1A,• T•'..! — '' FALLS CRX ADL000590 1 BHL ot....,...,,. rl S001 NO13W-- S001 NO12W ,,,,„/ / ,. --'FALLS CARK 1REISFIE''•-,.. / 1— ' ' ' TT,-• T.t... I,I,r,-.:1, r• 1'..1.. 4 INILC / "1-act:42-'' 7-..• .< I ' --Pry le - ,.. ". , UNI , - __„-- . , L - ,,, T•• , , _ Trn:t t,.'.. 1... - , . I / ‘ 1 Legend 0 . . :::\14%ci,........ ,,,, _.............loa_.,_--=';'...FRANCES ..., 7 , -I:_0 t hee rri Lt.!ttr^:e:i.ele.:zr.a:co,r ta0B-- f f t • Tr Lu5.4 / i gga24-5-P9 ' A wee -wen t, Prvate • FRANCES POI SIM 1::::1 SPE Parzels Oa And Bas POrnetpramoATen OE and Gad Una BOJndar, MG Traci 3 T otg 1-5 , 8 $ ,,t kile:".;:,,,,::' .t• ttt,t :.,t, , •L marix- .4.0(4024 y19. n Ninilchik Unit Falls Creek 6 . 1 000 Feet 2,000 ••., AMU Stade Plane zone 4, 1AD27 A. Map Bahr:firl 512014 Page 47 Version 1 Sept, 2014 Falls Creek#6 11 FDrilling Procedure Hi1COrp Energy Company 31.0 Surface Plat (As Staked) (NAD 27) sGa0�$'cry i�1u7CERtYOL L -' - - Sy see a, rra, R11iIp stK / ' 6:DIr7 t ar 3 dr N 1/3 SE" Or fYCI:.LIWC +rY ?l1-1 165 rt. / t r i t If I ,'%%" f isti.w71 lex vx A IE .l� I. 2895J FEL : A. / FALLS CREEK NO.8 +I 5 h 41*. AS-STAKED r 'rr NAO27ASP ZONE 4 - e I r, rr N:22693932 .0 j E 239332.3 I ui LATITUDE'60-iris 294'N LONGITUDE:151°254.8.452 W 41 j LL X31 FS 6.9 NAIJDBB • 2895'FEL • SECTION 6TIN R12W , ............. SCALE TMu .1 1 I I tt.I 'ECTaONCOMEm N 72E14WI 3 _ , _ . _ .__. tztu me N3TtO scALEE-242M 424 SCCa 1'e. •OASIS OF GEODETIC CONTROL.AND NAD63 POSITION(EPOCH 2003) - 1/19 -ry r C n IS AN OPUS SOLUTION FROM NGS COORDINATES STATIONS*KENS 1��t ATE R S FRAM TIES*o �, ��ilp T14.E'14i Sh4 ELM CORS ARP','TSEA ANCHORAGE CORS ARP',AND'ZANt �N. WON th CN'S COLND VMS ANCHORAGE WAAS 1 CORS ARP'TO ESTABLISH THE POSITION OF ''. PFT s Nal NONA FCRT. THE GEODE-11C POSITION OF FRC7 WAS DETERMINED TO — % le L tarrucuwues HAVE ALATITUDE OF60'SZ15.SG239'MIAND ALONGITUDE OF — 151'29'46.6459 W,THE ALASKA STATE PLANE COORDINATES IMP! .!* 499 .YYY lLL TIT ZONE 4 ARE: N=22199306.530 a 40 E-13812349.588 ELEV.250.96'(M VD88) 2)SECTION LINE OFFSETS DETERMINED FROM MONUMAENTED rt SECTION CORNER VALUES. ..�09,12114 31 NAD83 COORDINATES CONVERTED TO NAD27 WITH ,� •,„, •. NORTH CORPSCON CONVERSION SOFTWARE';FRSICIN r 1 t HHILCORP ALASKA LLC ,,.,,,^ , 3800 CENTERPOINT DR. '',.:,-,t,:- FANS CREEK NO.5 U'JEL! AS STAKED an, „,,,,.. ANCHORAGE,Ate 99503'5826 SURFACE LOCATION DIAGRAM NAD27 / rrnann on—, ,...o..„,no ON FALLS CREEK PRODUCTION PAD W ono.,,r,.u. Lsrzr rt..NM.% A...... ....'...,No w° DMA lq. 14A4 C....11rgMv_ a anoe4esnuearrNN.rune .ocrim” SEC,6T9N,..,,, ' ..._,..___ VOCE.9YSi519i:N %V.MOON NV IMM .# 'VIP" m400 1°,�""a�''"°`o.nu SEWARD MERIDIAN,ALASKA r° 1 Page 48 Version 1 Sept,2014 Falls Creek#6 Drilling Procedure Hilcorp Energy Company 32.0 Offset MW vs TVD Chart Falls Creek#6 Offset Wells 0 � 1000 I € Paxton#1 Paxton#2 2000 ` t FaIlsCreek#3 Falls Creek#4 3000 ‘L Frances#1 -Susan Dionne 8 4000 lib Fa Hs Creek#5 Wir .41 /V75> ete,-04 5000 / ,,,,, „ 6000 0 7000 3000 9000 1 t i 3 10000 11000 } ; 1 � E 12000 3 E 13000 3 f 14000 8 9 10 11 12 13 14 15 Mud Weight(PPG) Page 49 Version 1 Sept, 2014 RECEIVED SEP 1 8 2014 AOGCC Hilcorp Energy Company Ninilchik Unit Falls Creek Falls Creek #6 Falls Creek 6 Plan: Falls Creek 6 WP4.0 Standard Proposal Report 18 September, 2014 HALLIBURTON II Sperry Drilling Services ORIGINAL WE AILS: Falls Creek#6 HALLIBURTON Ground Level: 172.00 +N/-S +E/-W Northing Easting Latittude Longitude Slot Sperry Drilling 0.00 0.00 2269393.20 239932.30 60.20424845 -151.42957002 Project: Ninilchik Unit CASING DETAILS Hilcorp Energy Company Site: Falls Creek TVD MD Name Size Calculation Method: Minimum Curvature Well: Falls Creek#6 3389.11 3600.00 9 5/8" 9-5/8 Error System: ISCWSA 8690.00 9580.62 5 1/2" 5-1/2 Scan Method: Closest Approach 3D Wellbore: Falls Creek 6 Error Surface: Elliptical Conic Falls Creek 6 WP4.0 Warning Method: Error Ratio SECTION DETAILS Sec MD Inc Azi ND +N/-S +E/-W Dleg TFace VSect Target 1 18.00 0.00 0.00 18.00 0.00 0.00 0.00 0.00 0.00 2 275.00 0.00 0.00 275.00 0.00 0.00 0.00 0.00 0.00 3 475.00 2.00 320.00 474.96 2.67 -2.24 1.00 320.00 3.37 4 775.00 8.00 320.00 773.68 22.69 -19.04 2.00 0.00 28.58 5 1306.57 23.39 337.76 1284.12 149.51 -83.16 3.00 26.15 170.59 6 7822.05 23.39 337.76 7264.25 2543.59 -1061.96 0.00 0.00 2754.55 7 8295.20 37.56 336.09 7671.00 2763.47 -1156.43 3.00 -4.17 2993.79 FC6 T-60 Tgt 1500- 8 9580.62 37.56 336.09 8690.00 3479.78 -1474.02 0.00 0.00 3777.26 FC6 BHL Tgt - SURVEY PROGRAM Date:2014-09-18T00:00:00 Validated:Yes Version: -750- - Depth From Depth To Survey/Plan Tool 18.00 1000.00 Falls Creek 6 WP4.0(Falls Creek 6) NSG WL 1000.00 3600.00 Falls Creek 6 WP4.0(Falls Creek 6) MWD+SC+sag 3600.00 9580.62 Falls Creek 6 WP4.0(Falls Creek 6) MWD+SC+sag 0- Start Dir 1°/100':275'MD,275T/D Start Dir 2°/100':475'MD,474.96'TVD REFERENCE INFORMATION 750- Co-ordinate(N/E)Reference: Well Falls Creek#6,True North Start Dir 3°/100':775'MD,773.68'TVD Vertical(ND)Reference: Falls Creek 6 Prelim @ 190.00usft Measured Depth Reference: Falls Creek 6 Prelim @ 190.00usft Calculation Method: Minimum Curvature 1500- End Dir :1306.57'MD,1284.12'TVD 2250- - 250- - 3000- _ 9 5/8" \°' - 3750- CD m U r 4500- - _tll Beluga 135 2 52cn- Tyonek - -T-8 6000- T-10 Start Dir 3°/100':7822.05'MD,7264.25T/D - 6750- - -T-50 End Dir :8295.2'MD,7671'TVD 7500 - - _ T-60 FC6 1-60 Tgt 8250- -T-65 FC6 BHL Tgt 5 1/2" Total Depth:9580.62'MD,8690'ND 9000- = Falls Creek 6 WP4.0 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I -1500 -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 Vertical Section at 335.25°(1500 usft/in) COMPANY DETAI (corp Energy Company Project: Ninilchik Unit HA LLI B U R TO N Calculation Method:Minimum Curvature Site: Falls Creek Error System: ISCWSA Well: Falls Creek#6 -�`'-' --'----- Scan Method: Closest Approach 3D Sperry Drilling Error Surface: Elliptical Conic Wellbore: Falls Creek 6 Warning Method:Error Ratio Falls Creek 6 WP4.0 REFERENCE INFORMATION SECTION DETAILS Co-ordinate(N/E)Reference: Well Falls Creek#6,True North Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Vertical(TVD)Reference: Falls Creek 6 Prelim @ 190.00usft 1 18.00 0.00 0.00 18.00 0.00 0.00 0.00 0.00 0.00 Measured Depth Reference: Falls Creek 6 Prelim @ 190.00usft Calculation Method: Minimum Curvature 2 275.00 0.00 0.00 275.00 0.00 0.00 0.00 0.00 0.00 3 475.00 2.00 320.00 474.96 2.67 -2.24 1.00 320.00 3.37 4 775.00 8.00 320.00 773.68 22.69 -19.04 2.00 0.00 28.58 5 1306.57 23.39 337.76 1284.12 149.51 -83.16 3.00 26.15 170.59 6 7822.05 23.39 337.76 7264.25 2543.59 -1061.96 0.00 0.00 2754.55 7 8295.20 37.56 336.09 7671.00 2763.47 -1156.43 3.00 -4.17 2993.79 FC6 T-60 Tgt 8 9580.62 37.56 336.09 8690.00 3479.78 -1474.02 0.00 0.00 3777.26 FC6 BHL Tgt WELL DETAILS: Falls Creek#6 Ground Level: 172.00 J +N/-S +E/-W Northing Easting Latittude Longitude Slot 0.00 0.00 2269393.20 239932.30 60.20424845 -151.42957002 Falls Creek 6 WP4.0 5 1/2" 3600- SURVEY PROGRAM ---95%conf Date:2014-09-18T00:00:00 Validated:Yes Version: 3400- Depth From Depth To Survey/Plan Tool 18.00 1000.00 Falls Creek 6 WP4.0(Falls Creek 6) NSG WL FC6 BHL Tgt 1000.00 3600.00 Falls Creek 6 WP4.0(Falls Creek 6) MWD+SC+sag 3600.00 9580.62 Falls Creek 6 WP4.0(Falls Creek 6) MWD+SC+sag 3200- Total Depth:9580.62'MD,8690'TVD CASING DETAILS 3000- ND MD Name Size 3389.11 3600.00 9 5/8" 9-5/8 95%conf. 8690.00 9580.62 5 1/2" 5-1/2 2800- - End Dir :8295.2'MD,7671'TVD 2600- FC6 T-60 Tgt 2400 - Start Dir 3"/100':7822.05'MD,7264.25'TVD 2200- c 0• 2000- o • 1800- 1600- = - 0 rn - 1400- 1200- - 9 5/8" 1000- Soo- End Dir :1306.57'MD,1284.12'TVD 600- Start Dir 3°/100':775'MD,773.68'TVD 400- - Start Dir 2°/100':475'MD,474.96'TVD 200- - --- it - Start Dir 1°/100':275'MD,275'TVD -_____-- o-, 1 r I 1 1 1 1 I 1 1 1 1 I 1 1 1 1 I 1 1 1 1 I 1 I I r I r r r r I 1111111111111111 I I I 1 1 1 1 1 1 1 I I I I l I l -2400 -2200 -2000 -1800 -1600 -1400 -1200 -1000 -800 -600 -400 -200 0 200 400 600 800 1000 1200 West(-)/East(+)(500 usft/in) HA LLI B U RTO N .Vest(-)/East(+)(150 usft/in) -120 -60 0 60 120 180 240 __ • . •• '• i 300 Project: Ninilchik Unit Site: Falls Creek Well: Falls Creek#6 240 Wellbore: Falls Creek 6 Falls Creek 6 WP4.0 180 0 0 .5 a- 120 2 0 Falls Creek#3 60 3 l v: 0 0 y Fa Is C, - #1 5 1/2" -60 3740— i Falls Creek 6 WP4.08690 Falls Creek#4 Falls Creek 5 wp3 -120 3400— = Falls Creek 5 3060— $000 2720— 1000 2380— 2040— 6003 1700— 5000 1360- 1 = &000 Z - 3 - 9 5/8" 0 1020—kr, Q 00 p0 + - az 0 30 0 680 mom» o O = alleCreek a oa 2000 0 CD s 340— o c = 0 0 ^o 00 c s o c .% 0— _ h v y Falls Creek#1 RD Oo 0 __ 0 ° 1000 0 o o -340— c a g 0 0 ,o = o c 9, -680 "reek o 0 0 0 000 0 0 0 4020 `.•-- 0 alis CreelF#4 = 4§9Ils Creek 5 -1360— ? 6000 -1700— 2040- 6000 Falls Creek 5 wp3 2380—III IIIjIIIIIIIIIjIIiIiIIIIII r'fittilIIIIIIIIIiiIIIIIIiiIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIr -3740 -3400 -3060 -2720 -2380 -2040 -1700 -1360 -1020 -680 -340 0 340 680 1020 1360 1700 2040 2380 West(-)/East(+)(850 usft/in) Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Falls Creek#6 Company: Hilcorp Energy Company TVD Reference: Falls Creek 6 Prelim©190100usft . 7 , ..7y Project: Ninilchik Unit MD Reference: Falls Creek 6 Prelim©190.00usft /� Site: Falls Creek North Reference: True / �g • Well: Falls Creek#6 Survey Calculation Method: Minimum Curvature • r/ 9.4e-44 Wellbore: Falls Creek 6 i a/� Design: Falls Creek 6 WP4.0 Project Ninilchik Unit 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 Using geodetic scale factor Site Falls Creek Site Position: Northing: 2,269,493.23 usft Latitude: 60.20452798 From: Map Easting: 240,032.38 usft Longitude: -151.42903197 Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -1.24 ° Well Falls Creek#6 Well Position +N1-S 0.00 usft Northing: 2,269,393.20 usft Latitude: 60.20424845 +E/-W 0.00 usft Easting: 239,932.30 usft • Longitude: -151.429570 Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: LVgf O usft Wellbore Falls Creek 6 - 9-/Y- 4 Magnetics Model Name Sample Date Declination Dip Angle Field Strength el (°) (nT) BGGM2014 9/8/2014 16.70 73.21 55,240 Design Falls Creek 6 WP4.0 Audit Notes: Version: Phase: PLAN Tie On Depth: 18.00 Vertical Section: Depth From(ND) +NI-S +EI-W Direction (usft) (usft) (usft) (°) 18.00 0.00 0.00 335.25 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +NI-S +E/-W Rate Rate Rate Tool Face (usft) (°) (°) (usft) usft (usft) (usft) (°/100usft) (°/100usft) (°I100usft) (^) 18.00 0.00 0.00 18.00 -172.00 0.00 0.00 0.00 0.00 0.00 0.00 275.00 0.00 0.00 275.00 85.00 0.00 0.00 0.00 0.00 0.00 0.00 475.00 2.00 320.00 474.96 284.96 2.67 -2.24 1.00 1.00 0.00 320.00 775.00 8.00 320.00 773.68 583.68 22.69 -19.04 2.00 2.00 0.00 0.00 1,306.57 23.39 337.76 1,284.12 1,094.12 149.51 -83.16 3.00 2.89 3.34 26.15 7,822.05 23.39 337.76 7,264.25 7,074.25 2,543.59 -1,061.96 0.00 0.00 0.00 0.00 8,295.20 37.56 336.09 7,671.00 7,481.00 2,763.47 -1,156.43 3.00 2.99 -0.35 -4.17 9,580.62 37.56 336.09 8,690.00 8,500.00 3,479.78 -1,474.02 0.00 0.00 0.00 0.00 9/18/2014 11:26.29AM Page 2 COMPASS 5000.1 Build 70 Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Falls Creek#6 Company: Hilcorp Energy Company TVD Reference: Falls Creek 6 Prelim @ 190.00usft Project: Ninilchik Unit MD Reference: Falls Creek 6 Prelim©190.00usft Site: Falls Creek North Reference: True Well: Falls Creek#6 Survey Calculation Method: Minimum Curvature Wellbore: Falls Creek 6 Design: Falls Creek 6 WP4.0 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) -172.00 18.00 0.00 0.00 18.00 -172.00 0.00 0.00 2,269,393.20 239,932.30 0.00 0.00 100.00 0.00 0.00 100.00 -90.00 0.00 0.00 2,269,393.20 239,932.30 0.00 0.00 200.00 0.00 0.00 200.00 10.00 0.00 0.00 2,269,393.20 239,932.30 0.00 0.00 275.00 0.00 0.00 275.00 85.00 0.00 0.00 2,269,393.20 239,932.30 0.00 0.00 Start Dir 1°/100':275'MD,275'TVD 300.00 0.25 320.00 300.00 110.00 0.04 -0.04 2,269,393.24 239,932.27 1.00 0.05 400.00 1.25 320.00 399.99 209.99 1.04 -0.88 2,269,394.26 239,931.45 1.00 1.32 475.00 2.00 320.00 474.96 284.96 2.67 -2.24 2,269,395.92 239,930.11 1.00 3.37 Start Dir 2°I100':475'MD,474.96'TVD 500.00 2.50 320.00 499.94 309.94 3.43 -2.87 2,269,396.69 239,929.50 2.00 4.31 600.00 4.50 320.00 599.75 409.75 8.10 -6.80 2,269,401.45 239,925.68 2.00 10.20 700.00 6.50 320.00 699.28 509.28 15.44 -12.96 2,269,408.92 239,919.68 2.00 19.45 775.00 8.00 320.00 773.68 583.68 22.69 -19.04 2,269,416.30 239,913.75 2.00 28.58 Start Dir 3°/100':775'MD,773.68'TVD 800.00 8.68 322.19 798.42 608.42 25.52 -21.32 2,269,419.17 239,911.54 3.00 32.10 900.00 11.48 328.33 896.87 706.87 39.95 -31.17 2,269,433.82 239,902.00 3.00 49.33 1,000.00 14.37 332.05 994.32 804.32 59.39 -42.22 2,269,453.49 239,891.38 3.00 71.61 1,100.00 17.29 334.55 1,090.52 900.52 83.78 -54.42 2,269,478.13 239,879.70 3.00 98.86 1,200.00 20.24 336.34 1,185.20 995.20 113.04 -67.76 2,269,507.68 239,867.01 3.00 131.02 1,300.00 23.19 337.69 1,278.09 1,088.09 147.11 -82.18 2,269,542.05 239,853.33 3.00 168.00 1,306.57 23.39 337.76 1,284.13 1,094.13 149.51 -83.16 2,269,544.47 239,852.40 3.00 170.59 End Dir :1306.57'MD,1284.12'TVD 1,400.00 23.39 337.76 1,369.88 1,179.88 183.84 -97.20 2,269,579.10 239,839.11 0.00 207.65 1,500.00 23.39 337.76 1,461.66 1,271.66 220.59 -112.22 2,269,616.16 239,824.88 0.00 247.31 1,600.00 23.39 337.76 1,553.45 1,363.45 257.33 -127.24 2,269,653.22 239,810.66 0.00 286.96 1,700.00 23.39 337.76 1,645.23 1,455.23 294.08 -142.27 2,269,690.28 239,796.44 0.00 326.62 1,800.00 23.39 337.76 1,737.01 1,547.01 330.82 -157.29 2,269,727.34 239,782.22 0.00 366.28 1,900.00 23.39 337.76 1,828.80 1,638.80 367.56 -172.31 2,269,764.40 239,767.99 0.00 405.94 2,000.00 23.39 337.76 1,920.58 1,730.58 404.31 -187.33 2,269,801.46 239,753.77 0.00 445.60 2,100.00 23.39 337.76 2,012.36 1,822.36 441.05 -202.36 2,269,838.52 239,739.55 0.00 485.26 2,200.00 23.39 337.76 2,104.15 1,914.15 477.80 -217.38 2,269,875.58 239,725.32 0.00 524.92 2,300.00 23.39 337.76 2,195.93 2,005.93 514.54 -232.40 2,269,912.64 239,711.10 0.00 564.58 2,400.00 23.39 337.76 2,287.71 2,097.71 551.29 -247.42 2,269,949.70 239,696.88 0.00 604.23 2,500.00 23.39 337.76 2,379.50 2,189.50 588.03 -262.45 2,269,986.76 239,682.65 0.00 643.89 2,600.00 23.39 337.76 2,471.28 2,281.28 624.78 -277.47 2,270,023.82 239,668.43 0.00 683.55 2,700.00 23.39 337.76 2,563.06 2,373.06 661.52 -292.49 2,270,060.88 239,654.21 0.00 723.21 2,800.00 23.39 337.76 2,654.85 2,464.85 698.27 -307.51 2,270,097.94 239,639.98 0.00 762.87 2,900.00 23.39 337.76 2,746.63 2,556.63 735.01 -322.54 2,270,135.00 239,625.76 0.00 802.53 3,000.00 23.39 337.76 2,838.41 2,648.41 771.75 -337.56 2,270,172.06 239,611.54 0.00 842.19 3,100.00 23.39 337.76 2,930.20 2,740.20 808.50 -352.58 2,270,209.12 239,597.31 0.00 881.85 3,200.00 23.39 337.76 3,021.98 2,831.98 845.24 -367.61 2,270,246.18 239,583.09 0.00 921.50 3,300.00 23.39 337.76 3,113.76 2,923.76 881.99 -382.63 2,270,283.25 239,568.87 0.00 961.16 3,400.00 23.39 337.76 3,205.55 3,015.55 918.73 -397.65 2,270,320.31 239,554.64 0.00 1,000.82 I 3,500.00 23.39 337.76 3,297.33 3,107.33 955.48 -412.67 2,270,357.37 239,540.42 0.00 1,040.48 9/18/2014 11 26.29AM Page 3 COMPASS 5000.1 Build 70 Halliburton HALLIBLiRTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Falls Creek#6 Company: Hilcorp Energy Company TVD Reference: Falls Creek 6 Prelim @ 190.00usft Project: Ninilchik Unit MD Reference: Falls Creek 6 Prelim @ 190.00usft Site: Falls Creek North Reference: True Well: Falls Creek#6 Survey Calculation Method: Minimum Curvature Wellbore: Falls Creek 6 Design: Falls Creek 6 WP4.0 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Veil Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 3,199.11 3,600.00 23.39 337.76 3,389.11 3,199.11 992.22 -427.70 2,270,394.42 239,526.20 0.00 1,080.14 9 5/8" 3,700.00 23.39 337.76 3,480.90 3,290.90 1,028.97 -442.72 2,270,431.49 239,511.97 0.00 1,119.80 3,800.00 23.39 337.76 3,572.68 3,382.68 1,065.71 -457.74 2,270,468.55 239,497.75 0.00 1,159.46 3,900.00 23.39 337.76 3,664.46 3,474.46 1,102.45 -472.76 2,270,505.61 239,483.53 0.00 1,199.12 4,000.00 23.39 337.76 3,756.25 3,566.25 1,139.20 -487.79 2,270,542.67 239,469.30 0.00 1,238.77 4,100.00 23.39 337.76 3,848.03 3,658.03 1,175.94 -502.81 2,270,579.73 239,455.08 0.00 1,278.43 4,200.00 23.39 337.76 3,939.81 3,749.81 1,212.69 -517.83 2,270,616.79 239,440.86 0.00 1,318.09 4,300.00 23.39 337.76 4,031.60 3,841.60 1,249.43 -532.85 2,270,653.85 239,426.64 0.00 1,357.75 4,400.00 23.39 337.76 4,123.38 3,933.38 1,286.18 -547.88 2,270,690.91 239,412.41 0.00 1,397.41 4,500.00 23.39 337.76 4,215.16 4,025.16 1,322.92 -562.90 2,270,727.97 239,398.19 0.00 1,437.07 4,600.00 23.39 337.76 4,306.95 4,116.95 1,359.67 -577.92 2,270,765.03 239,383.97 0.00 1,476.73 4,700.00 23.39 337.76 4,398.73 4,208.73 1,396.41 -592.95 2,270,802.09 239,369.74 0.00 1,516.39 4,800.00 23.39 337.76 4,490.51 4,300.51 1,433.16 -607.97 2,270,839.15 239,355.52 0.00 1,556.04 4,900.00 23.39 337.76 4,582.30 4,392.30 1,469.90 -622.99 2,270,876.21 239,341.30 0.00 1,595.70 5,000.00 23.39 337.76 4,674.08 4,484.08 1,506.64 -638.01 2,270,913.27 239,327.07 0.00 1,635.36 5,100.01 23.39 337.76 4,765.86 4,575.86 1,543.39 -653.04 2,270,950.33 239,312.85 0.00 1,675.02 5,200.01 23.39 337.76 4,857.65 4,667.65 1,580.13 -668.06 2,270,987.39 239,298.63 0.00 1,714.68 5,252.69 23.39 337.76 4,906.00 4,716.00 1,599.49 -675.97 2,271,006.91 239,291.13 0.00 1,735.57 Beluga 135 5,300.01 23.39 337.76 4,949.43 4,759.43 1,616.88 -683.08 2,271,024.45 239,284.40 0.00 1,754.34 5,400.01 23.39 337.76 5,041.21 4,851.21 1,653.62 -698.10 2,271,061.51 239,270.18 0.00 1,794.00 5,500.01 23.39 337.76 5,133.00 4,943.00 1,690.37 -713.13 2,271,098.57 239,255.96 0.00 1,833.66 5,528.34 23.39 337.76 5,159.00 4,969.00 1,700.78 -717.38 2,271,109.07 239,251.93 0.00 1,844.89 Tyonek 5,600.01 23.39 337.76 5,224.78 5,034.78 1,727.11 -728.15 2,271,135.63 239,241.73 0.00 1,873.31 5,700.01 23.39 337.76 5,316.56 5,126.56 1,763.86 -743.17 2,271,172.69 239,227.51 0.00 1,912.97 5,800.01 23.39 337.76 5,408.35 5,218.35 1,800.60 -758.19 2,271,209.75 239,213.29 0.00 1,952.63 5,900.01 23.39 337.76 5,500.13 5,310.13 1,837.34 -773.22 2,271,246.81 239,199.06 0.00 1,992.29 6,000.01 23.39 337.76 5,591.91 5,401.91 1,874.09 -788.24 2,271,283.87 239,184.84 0.00 2,031.95 6,100.01 23.39 337.76 5,683.70 5,493.70 1,910.83 -803.26 2,271,320.93 239,170.62 0.00 2,071.61 6,200.01 23.39 337.76 5,775.48 5,585.48 1,947.58 -818.29 2,271,357.99 239,156.39 0.00 2,111.27 6,300.01 23.39 337.76 5,867.26 5,677.26 1,984.32 -833.31 2,271,395.05 239,142.17 0.00 2,150.93 6,316.06 23.39 337.76 5,882.00 5,692.00 1,990.22 -835.72 2,271,401.00 239,139.89 0.00 2,157.29 T-8 6,400.01 23.39 337.76 5,959.05 5,769.05 2,021.07 -848.33 2,271,432.11 239,127.95 0.00 2,190.58 6,500.01 23.39 337.76 6,050.83 5,860.83 2,057.81 -863.35 2,271,469.17 239,113.72 0.00 2,230.24 6,600.01 23.39 337.76 6,142.61 5,952.61 2,094.56 -878.38 2,271,506.23 239,099.50 0.00 2,269.90 6,623.31 23.39 337.76 6,164.00 5,974.00 2,103.12 -881.88 2,271,514.87 239,096.19 0.00 2,279.14 T-10 6,700.01 23.39 337.76 6,234.40 6,044.40 2,131.30 -893.40 2,271,543.30 239,085.28 0.00 2,309.56 6,800.01 23.39 337.76 6,326.18 6,136.18 2,168.04 -908.42 2,271,580.36 239,071.06 0.00 2,349.22 6,900.01 23.39 337.76 6,417.96 6,227.96 2,204.79 -923.44 2,271,617.42 239,056.83 0.00 2,388.88 7,000.01 23.39 337.76 6,509.75 6,319.75 2,241.53 -938.47 2,271,654.48 239,042.61 0.00 2,428.54 7,100.01 23.39 337.76 6,601.53 6,411.53 2,278.28 -953.49 2,271,691.54 239,028.39 0.00 2,468.20 9/18/2014 11:26.29AM Page 4 COMPASS 5000.1 Build 70 Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Falls Creek#6 Company: Hilcorp Energy Company TVD Reference: Falls Creek 6 Prelim©190.00usft Project: Ninilchik Unit MD Reference: Falls Creek 6 Prelim @ 190.00usft Site: Falls Creek North Reference: True Well: Falls Creek#6 Survey Calculation Method: Minimum Curvature Wellbore: Falls Creek 6 Design: Falls Creek 6 WP4.0 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (0) (^) (usft) usft (usft) (usft) (usft) (usft) 6,503.31 7,200.01 23.39 337.76 6,693.31 6,503.31 2,315.02 -968.51 2,271,728.60 239,014.16 0.00 2,507.85 7,300.01 23.39 337.76 6,785.10 6,595.10 2,351.77 -983.53 2,271,765.66 238,999.94 0.00 2,547.51 7,400.01 23.39 337.76 6,876.88 6,686.88 2,388.51 -998.56 2,271,802.72 238,985.72 0.00 2,587.17 7,500.01 23.39 337.76 6,968.66 6,778.66 2,425.26 -1,013.58 2,271,839.78 238,971.49 0.00 2,626.83 7,600.01 23.39 337.76 7,060.45 6,870.45 2,462.00 -1,028.60 2,271,876.84 238,957.27 0.00 2,666.49 7,700.01 23.39 337.76 7,152.23 6,962.23 2,498.75 -1,043.62 2,271,913.90 238,943.05 0.00 2,706.15 7,800.01 23.39 337.76 7,244.01 7,054.01 2,535.49 -1,058.65 2,271,950.96 238,928.82 0.00 2,745.81 7,822.05 23.39 337.76 7,264.24 7,074.24 2,543.59 -1,061.96 2,271,959.13 238,925.69 0.00 2,754.55 Start Dir 30/100':7822.05'MD,7264.25'TVD 7,900.01 25.72 337.37 7,335.15 7,145.15 2,573.53 -1,074.32 2,271,989.33 238,913.97 3.00 2,786.92 8,000.01 28.72 336.96 7,424.06 7,234.06 2,615.68 -1,092.08 2,272,031.85 238,897.13 3.00 2,832.63 8,027.41 29.54 336.86 7,448.00 7,258.00 2,627.94 -1,097.31 2,272,044.23 238,892.17 3.00 2,845.96 T-50 8,100.01 31.71 336.61 7,510.47 7,320.47 2,661.92 -1,111.92 2,272,078.51 238,878.30 3.00 2,882.92 8,200.01 34.71 336.33 7,594.13 7,404.13 2,712.12 -1,133.79 2,272,129.17 238,857.53 3.00 2,937.67 8,295.20 37.56 336.09 7,671.00 7,481.00 2,763.47 -1,156.43 2,272,181.00 238,836.00 3.00 2,993.79 End Dir :8295.2'MD,7671'TVD-T-60 8,300.01 37.56 336.09 7,674.82 7,484.82 2,766.15 -1,157.62 2,272,183.71 238,834.87 0.00 2,996.72 8,400.01 37.56 336.09 7,754.09 7,564.09 2,821.88 -1,182.33 2,272,239.95 238,811.38 0.00 3,057.67 8,500.01 37.56 336.09 7,833.36 7,643.36 2,877.61 -1,207.04 2,272,296.20 238,787.88 0.00 3,118.62 8,600.01 37.56 336.09 7,912.64 7,722.64 2,933.33 -1,231.74 2,272,352.45 238,764.39 0.00 3,179.57 8,700.01 37.56 336.09 7,991.91 7,801.91 2,989.06 -1,256.45 2,272,408.69 238,740.89 0.00 3,240.52 8,800.01 37.56 336.09 8,071.18 7,881.18 3,044.78 -1,281.16 2,272,464.94 238,717.40 0.00 3,301.47 8,804.82 37.56 336.09 8,075.00 7,885.00 3,047.47 -1,282.35 2,272,467.65 238,716.27 0.00 3,304.41 T-65 8,900.01 37.56 336.09 8,150.46 7,960.46 3,100.51 -1,305.86 2,272,521.18 238,693.90 0.00 3,362.42 9,000.01 37.56 336.09 8,229.73 8,039.73 3,156.23 -1,330.57 2,272,577.43 238,670.41 0.00 3,423.37 9,100.01 37.56 336.09 8,309.00 8,119.00 3,211.96 -1,355.28 2,272,633.67 238,646.92 0.00 3,484.32 9,200.01 37.56 336.09 8,388.28 8,198.28 3,267.68 -1,379.98 2,272,689.92 238,623.42 0.00 3,545.28 9,300.01 37.56 336.09 8,467.55 8,277.55 3,323.41 -1,404.69 2,272,746.17 238,599.93 0.00 3,606.23 9,400.01 37.56 336.09 8,546.82 8,356.82 3,379.13 -1,429.40 2,272,802.41 238,576.43 0.00 3,667.18 9,500.01 37.56 336.09 8,626.10 8,436.10 3,434.86 -1,454.11 2,272,858.66 238,552.94 0.00 3,728.13 9,580.62 37.56 336.09 8,690.00, 8,500.00 3,479.78 • -1,474.02 , 2,272,904.00 238,534.00 0.00 3,777.26 Total Depth:9580.62'MD,8690'TVD-5 1/2" Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +NI-S +E/-W Northing Easting -Shape (°) (0) (usft) (usft) (usft) (usft) (usft) FC6 BHL Tgt 0.00 0.00 8,690.00 3,479.78 -1,474.02 2,272,904.00 238,534.00 -plan hits target center -Circle(radius 100.00) FC6 T-60 Tgt 0.00 0.00 7,671.00 2,763.47 -1,156.43 2,272,181.00 238,836.00 -plan hits target center -Circle(radius 100.00) 9/18/2014 11 26:29AM Page 5 COMPASS 5000.1 Build 70 Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Falls Creek#6 Company: Hilcorp Energy Company TVD Reference: Falls Creek 6 Prelim @ 190.00usft Project: Ninilchik Unit MD Reference: Falls Creek 6 Prelim©190.00usft Site: Falls Creek North Reference: True Well: Falls Creek#6 Survey Calculation Method: Minimum Curvature Wellbore: Falls Creek 6 Design: Falls Creek 6 WP4.0 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 3,600.00 3,389.11 95/8" 9-5/8 12-1/4 9,580.62 8,690.00 5 1/2" 5-1/2 8-1/2 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (usft) (usft) Name Lithology (°) (°) 5,528.34 5,159.00 Tyonek 6,316.06 5,882.00 T-8 6,623.31 6,164.00 1-10 8,295.20 7,671.00 T-60 8,804.82 8,075.00 T-65 8,027.41 7,448.00 T-50 5,252.69 4,906.00 Beluga 135 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +EI-W (usft) (usft) (usft) (usft) Comment 275.00 275.00 0.00 0.00 Start Dir 1°/100':275'MD,275'TVD 475.00 474.96 2.67 -2.24 Start Dir 2°/100':475'MD,474.96'TVD 775.00 773.68 22.69 -19.04 Start Dir 3°/100':775'MD,773.68'TVD 1,306.57 1,284.13 149.51 -83.16 End Dir :1306.57'MD,1284.12'TVD 7,822.05 7,264.24 2,543.59 -1,061.96 Start Dir 3°/100':7822.05'MD,7264.25'TVD 8,295.20 7,671.00 2,763.48 -1,156.43 End Dir :8295.2'MD,7671'TVD 9,580.62 8,690.00 3,479.78 -1,474.02 Total Depth:9580.62'MD,8690'TVD 9/18/2014 11:26.29AM Page 6 COMPASS 5000.1 Build 70 to m 0L � rg L m o C M W L Mal aa ` L m = a di di I 07 Min till R O. di m v 3 • a `� m m e ) q `o T C M ..-0 a O N y O W O d K ` in K w s O `/RV 'o UN 2 O N .- .c0 r a + LL Z .d O • csi r- w-- 0 O C y N f p • 3 UQ • LL t0 r n 7 d I� W "n w S °1 11 U 3 T • # p Y y M 0 W Q U N O > LL L a U m m e W o c N M,si 2 ` a O 0 co W z d N Q a _ I WC 2� a) .� �_ z•E e8: = .w ■- LI 0 O N 01 G`01 co d O J FL/1 t t0 to c = N a m ctO, U Cr; N Ti m o Y� Y� Y�� Y ' y Cl LL N N o , g 7 p o i W 0 W 0 0 .Q c m h LL LL m (7 N ' w 0 Y i i i d a) L o m .. o m m o (13 ■� d a p c t 6 m m o v U) y N �v) a. 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Let me know if there is anything else you require regarding this well. From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Monday, September 29, 2014 11:00 AM To: Luke Keller Subject: RE: Falls Creek #6 Directional Plan Luke, Could Hilcorp please provide a copy of the directional plan for the revised Falls Creek#6 well? (Revised permit application received 9/25/2014.) Thanks, Steve Davies AOGCC 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Luke Keller [mailto:lkeller@hilcorp.com] Sent: Thursday, September 18, 2014 11:16 AM To: Davies, Stephen F (DOA) Subject: FW: Falls Creek #6 Directional Plan Steve, Attached is the corrected version of the directional plan. Thank you again for catching that! Luke 1 II Davies, Stephen F (DOA) From: David Duffy <dduffy@hilcorp.com> Sent: Thursday, September 25, 2014 5:12 PM To: Davies, Stephen F (DOA) Cc: Luke Keller Subject: RE: Falls Creek 6, Revised (Permit#2141370): Spacing Question Hi Steve. The wellbore is more than 1500'from the unit boundary. The productive interval is entirely within the Falls Creek PA. There are no unleased tracts in the neighborhood. Under the new pool rules, no spacing exception will be required. Sec. 36 x,- _-_„Sec. 31 Sec. M ♦ I4. t S� y F 1' ; • • . : Yv 1 I * k t, i . ••••••.,..... . ,+ �� .. •fir ' *l. . .ik 1 1 J •II,a1 1 lk 1 11 :e 1,�. 1 "' " ! iy T ' * ,'S Iwo ,. .,' t t: % . JCC. 1 r t+ r• ` • ', SeC. 6,, f ,� ,� ! ;1� Sec1. ti ''' 1 ' f/i '` . li :e ti d ' 4 y•i l t ! *4-..*4-..4( . toe k r, i t dt t•. t a 4• i Rai 113R ! (t¢ ;t, lbs ( : Yflit11?n l �'1 'r. Si. ' y a. l is N. ,q� rj ; ri. A'4{. r 1'^ ' • L.A.' k • 0 .,1 ii . ",),.., •� i t', .v. if 1 David Duffy, Landman Hilcorp Alaska, LLC Direct: 907-777-8414 Cell: 907-301-2629 dduffy@hilcorp.com This email may contain confidential and / or privileged information and is intended for the recipient(s)only. In the event you receive this message in error, please notify me and delete the message. From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Thursday, September 25, 2014 3:56 PM To: Luke Keller; David Duffy Subject: Falls Creek 6, Revised (Permit #2141370): Spacing Question Luke, David: Will the Falls Creek 6 (Revised)well conform to the spacing requirements of the newly approved Ninilchik Unit Pool Rules(Conservation Order No. 701)? Thanks, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 2 Davies, Stephen F (DOA) From: Luke Keller <Ikeller@hilcorp.com> Sent: Thursday, September 18, 2014 8:59 AM To: Davies, Stephen F (DOA) Subject: Falls Creek#6 Directional Plan Attachments: Falls Creek#6 WP4.0 Proposal Report.pdf; Falls Creek 6 WP4.0 GIS.txt; Falls Creek 6 WP4.0.txt Steve, Attached is our current plan for Falls Creek#6. The MD is about 30' different from what I have in the drilling program, but only because we keep tweaking things a little to try and find best approach around the other wells on the pad to avoid MWD interference. BHL and surface location are exactly the same. Let me know if you need anything else, or if you would like to see surveys in a different format. Luke Keller Drilling Engineer Hilcorp Alaska, LLC 907-777-8395 1 Davies, Stephen F (DOA) From: Luke Keller <Ikeller@hilcorp.com> Sent: Thursday, September 18, 2014 7:11 AM To: Davies, Stephen F (DOA) Subject: RE: Falls Creek 6 (PTD#214-137): Incomplete Application Steve, Sorry about this, I will get one that does not say DRAFT on it and send to you this morning. From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Wednesday, September 17, 2014 4:26 PM To: Luke Keller Subject: Falls Creek 6 (PTD #214-137): Incomplete Application Luke, Hilcorp's application for Falls Creek 6 does not include a proposed directional survey. Could you please provide one? Please let me know if you have any questions. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 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 Steve Davies at 907-793-1224 or steve.davies@alaska.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: f7/ &d.e L (O PTD: 2_167 //3 7 /Development Service Exploratory Stratigraphic Test Non-Conventional 7 FIELD: ,4///.4 /C ki 16- POOL: 41111' _ a)0 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 (Company Name) in the attached application, the following well logs ar also required for this well: 7 /,,c) fr >/ Well Logging /2 T�--4W4( L.t.se l— 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 /et`' / within 90 days after completion, suspension or abandonment of this well. < c /v__ t-7 Ad) ?- Revised 4/2014 E N . . . . , 0) O , . N Q , , . , , , a) , o . 4 , . 6. ae), , N. O, -0. , Z. 4 a), . , , , , . w• 2. is G kryV a J• O' a. E. V. N.0 O) •co' V• i, a7 O CV O' N' �' ' O' • a) ,n o o' o. 3' o, v. Tv o . . . aL o, O. o, '° O• . . . . . . . . . -o" Lr m, o. . v 8 . E. co, c �� co a) J, 'n 1?_ U, aL N W j O• � O• d , C, 0.. C . (tea. O, �, O, N• �, O , W, a• a t. =. o. ca. N. a. 0. 2 -c. P. • • • OOy °5. Ea) O) '} O. . O, aO � � G. Z ' a . . a, C >' ayJ ' occE. . 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To improve the readability of the Well History file and to simplrfy finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Falls Creek #6 Ninilchik Unit Kenai Peninsula Borough, Alaska October 19, 2014 – November 6, 2014 Provided by: Approved by: Dave Buthman Compiled by: Harry Bleys, Tyler Harris Distribution Date: December 30, 2014 Falls Creek #6 2 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW ................................................................................................3 1.1 Equipment Summary ......................................................................................................................3 1.2 Crew................................................................................................................................................3 2 GENERAL WELL DETAILS...................................................................................................................4 2.1 Well Objectives...............................................................................................................................4 2.2 Hole Data........................................................................................................................................4 2.3 Daily Activity Summary...................................................................................................................5 3 GEOLOGICAL DATA.............................................................................................................................7 3.1 Lithostratigraphy .............................................................................................................................7 3.2 Lithology Details..............................................................................................................................7 3.3 Sampling Program........................................................................................................................17 4 DRILLING DATA..................................................................................................................................18 4.1 Surveys.........................................................................................................................................18 4.2 Bit Record.....................................................................................................................................22 4.3 Mud Record ..................................................................................................................................23 4.4 Drilling Progress Chart..................................................................................................................24 5 SHOW REPORTS ...............................................................................................................................25 6 DAILY REPORTS ................................................................................................................................26 Enclosures 2” / 100’ Formation Log (MD/TVD) 5” / 100’ Formation Log (MD/TVD) 2” / 100’ LWD Combo Log (MD/TVD) 2” / 100’ Drilling Dynamics Log (MD/TVD) 2” / 100’ Gas Ratio Log (MD/TVD) Final Data CD Falls Creek #6 3 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type / Position Total Downtime Comments Computers – Surface Logging Rigwatch Server, Rigwatch Remote DML, LWD WITS, Rigwatch Remote 1 hour Lost Rigwatch for an hour at day light savings time Ditch gas QGM gas trap; Flame ionization total gas & chromatography. 17.5 hours QGM unplugged by rig electrician (0.5); Chromatograph failure (17) Hook Load / Weight on bit WITS from Pason 0.5 hours Power outage Mud Flow In Derived from Strokes/Minute and Pump Output 0.5 hours Power outage Mud Flow Out WITS from Pason 0.5 hours Power outage Pit Volumes, Pit Gain/Loss WITS from Pason 0.5 hours Power outage Pump Pressure WITS from Pason 0.5 hours Power outage Pump Stroke Counters (2) WITS from Pason 0.5 hours Power outage Rate of Penetration Calculated from Pason 0.5 hours Power outage RPM WITS from Pason 0.5 hours Power outage Torque WITS from Pason 0.5 hours Power outage WITS To/ From Pason Rigwatch Remote (HP Compaq) 0 hours 1.2 Crew Mud Logging Unit Type: Arctic Mud Logging Unit Number: ML030 Logging Geologists Years1 Days2 Sample Catchers Years Days2 Harry Bleys 14 17 Dickey Hudgins 4 15 Tyler Harris 1 23 Dylan Muller 3 20 *1 Years experience as Mudlogger *2 Days at wellsite between rig up and rig down of logging unit. Falls Creek #6 4 2 GENERAL WELL DETAILS 2.1 Well Objectives Falls Creek #6 is a Tyonek and Beluga gas development well, based on subsurface and 3D seismic controls, which indicate a flat structure to the northeast of the Falls Creek 1RD. Seismic indicates a T- 50/T-60 stratigraphic thick zone of interest, similar to that observed in the recently completed Frances 1 well, through the same reservoir unit. An AVO anomaly has also been mapped at the T-60 take point. The well has been designed to have a shallow kick off and gain separation from other wells on the Falls Creek pad. Operator: HILCORP ALASKA, LLC Well Name: Falls Creek #6 Field: Kenai Beluga Unit County: Kenai Peninsula Borough State: Alaska Company Representatives: Mike Leslie, Doug Yessak, James Lott, Shane Barber Location: Surface Coordinates 1906' FSL, 2730' FEL, Sec 6, T1N, R12W, SM, AK Ground ( Pad ) Elevation 248.3’ NGVD88 Rotary Table Elevation 266.8’ AMSL Classification: Development - Gas API #: 50-133-20645-00-00 Permit #: 214-137 Rig Name/Type: Saxon 147 / Land / Double Spud Date October 19, 2014 Total Depth Date: November 6, 2014 Total Depth 9060’ MD / 8292’ TVD / -8025’ TVDSS Primary Targets Beluga 135, Tyonek, T-8, T-10, T-50, T-60, T-65 Primary Target Depths 5461’, 5748’, 5566’, 6885’, 8229’, 5463’, 8886’ Total Depth Formation: Tyonek Completion Status: Cased LWD-MWD Services. Halliburton/ Sperry Drilling Services Directional Drilling Halliburton/ Sperry Drilling Services Wireline Logging Services Well wire lined on 11/07/2014 Drilling Fluids Service M.I. Swaco 2.2 Hole Data Max Depth Shoe Depth Hole Section MD (ft) TVD (ft) TD Formation MW ppg Dev oinc Csg Dia MD (ft) TVD (ft) FIT ppg 12 ¼” 3530’ 3345’ Beluga 9.0 25.69 9 5/8” 3498’ 3316.88 12.0 8 ½” 9060 8292 Tyonek 9.4 35.55 5 1/2” 9060’ 8292’ NA Falls Creek #6 5 2.3 Daily Activity Summary 10/18/2014: Carnig began rigging up. 10/19/20: Finish rigging up. Pick up 5" drill pipe. 10/20/2014: Drilled to 1979'. Short trip to Collars. TIH and continue drilling. Trip gas 24 u. Off bottom 5.5 hrs. 10/21/2014: Drill ahead to 1979'. CBU. Pump sweep. Wiper trip to 319'. Service rig. RIH. Drill ahead - WOB 13 RPM 80 TQ 8-10K GPM 570 SPP 1780. 10/22/2014: Drilled ahead with 12K WOB, 80 GPM, 1800psi SPP, rotating 100rpm and 65-100 ft/hr ROP to 3530' TD. Short tripped with no issues and circulated a sweep when back on bottom. Continued circulating, pumped slug and POOH at time of report. 10/23/2014: Ran remaining 44 joints of 9 5/8 inch casing. Landed the casing and rigged down casing crew. Circulated and conditioned mud and rigged up cementing equipment and held a pre job safety meeting. At present performing cement job. Max gas was 20 u. of trip gas. 10/24/2014: Nipple up multi bowl well head and install pack off p-seal and test to 3 thousand psi for 15 minutes, while staging BOP stack in cellar. Install cellar doors. Continue to clean pits getting ready for KLA Shield mud. Performed a rig service on draw works. Check oil levels on top drive. Nipple up Top Rams and remove shipping beans. Nipple up mud cross, blind rams, and top rams. Nipple up choke and kill lines and install flow nipple, catch can, flow line, bleeder line, trip tank hose, and cross chain to stack. 10/25/2014: Finished nippling up. Rigged up choke, and installed fittings and rigged up koomey lines to BOP. Installed stack bolts and rigged up catch can, bell nipple, flow line, hole file line and two inch bleed off line. Rigged up gas buster dump line and welded a brace in place. Laid down bridle lines and rigged up bails and elevators. Commenced working on steam heat system for rig. Closed doors on sub and hang tarps. Fixed lights in derrick and rehung service loop sock. Began general house keeping, and began winterizing rig by fabricating steam coils for cutting box. and fabricated hard line steam header for all three mud pits. 10/26/2014: Continue to plumb in steam lines in hopper house, pump #3.in steam lines to pits, and to heat coil for shale tank. Installed steam heaters in pits and mounted new steam brackets and heater mounts with R&D welding. Fabricate and install jumper hoses as needed. Fabricate and install one inch hard line to choke for blowing down choke manifold. 10/27/2014: Continue to plumb in steam lines to cellar and cellar. Weld pipe clamps to cellar and pits for new steam lines. Weld heater mounts to rig floor and continue with rig services and house cleaning. build two inch return lines from pit to pump and pump to boiler. 10/28/2014: Finished welding in sub, and finalized steam project. Hung and plumbed heater on rig floor. Set and pin roof on mud tanks. Cut new holes for wind walls to hang . Brought test plug, wear bushing, and 5 inch test joint to rig floor. Finished steam hard line to pit module #1. Fabricated and installed 1 inch air line. 10/29/2014: Re-stepped 5 inch test plug and tested. Rigged down all test equipment and rigged up casing pressure test equipment. Test for thirty minutes at 2900 psi. Bleed off all pressure and open blind rams, and drain BOP stack. Blown down kill line and reset topdrive torque. Strap tally drill pipe. Rig up floor and derrick to pick up 100 joints of drill pipe. Run in hole. Falls Creek #6 6 10/30/14: Pulled out of hole and put on new tools for drilling. Tripped back in hole and drilled out cement and 20 ft of rathole. Performed FIT test to 12.0 ppg. Commenced drilling and still drilling at report time. Max gas 452u @ 3622 Ft. 11/31/2014: Drilled ahead all day until 5035 Ft. and stopped circulated bottoms up. Pumped a sweeps all around and commenced a short to the shoe. Max gas was 654 u. @ 4779 Ft. Trip gas 50 u at 5035 Ft. 11/01/2014: Drilled ahead all day until 5035’, and stopped circulated bottoms up . Pumped a sweep all around and commenced a short trip to the shoe. Max gas was 654 u. @ 4779 Ft. Trip gas was 50u, at 5035 Ft. 11/02/2014: Drilled all day until 6109ft. and performed short trip to shoe. Circulated prior to short trip and pumped a sweep around. Tripped back in hole and reached bottom with 380 u. of trip gas. max gas was 908u @ 5070 ft. 11/03/2014: Drilled ahead all day and stopped and circulated and pumped a sweep than pulled a short trip 7117 Ft to the shoe. Tripped back to bottom and had 276u of trip gas. Max gas was 725 u at 6825 Ft. 11/04/2014: Drilled all day and started to lose stand pipe pressure. Continued lose over several hours of 400 psi in possible washout in drill pipe. Circulated a sweep out and flow checked the well, than continued to check for washed out drill pipe while tripping out of hole. Max gas 925 u at 7402'. 11/05/2014: Pumped two consecutive sweeps and got 75% returns and 50% returns. Held a pre job safety meeting and checked flow in the well, commenced pulling out of hole from 8484 ft. Had wiper gas of 657 u. at 8104 ft. and max gas of 991 at 8413 ft. 11/06/2014: Tripped out of hole to solve and work on mud pumps. Tripped back in and received 454 u of trip gas. Commenced drilling and still drilling at report time. Max gas 544 u. at 8652 ft. 11/07/2014: Drilled until 9060 ft. And TD well. Circulated bottoms up and pumped sweep and began tripping out of hole. Reached surface and began laying down tools. Broke open MWD tools and downloaded all data. Rigged down and rigged up to wireline well; tripped in hole and at present at 6879 ft. logging well. Max gas 599 u at 8987 ft. 11/08/2014: held safety meeting and prepared to rig up wireline crew. Rigged up and ran in hole, and latched survey tool into bit sub. Released from tool and wireline pulled out of hole. Hold safety meeting with wireline crew and rigged down wireline equipment. Pulled out of hole with memory logs. Rigged up SLB E-line to attempt to retrieve logging tools. No success so rigged down E-line. Commenced laying down drill pipe as pulling out of hole. Starting from 3201 ft.. 11/09/204: Circulate bottoms up and pump a slug prior to dropping wiper tool. Pull out of hole laying down drill pipe. Remove bit and bit sub. Drain blow out preventers and rig-up bushing puller and pull wear bushing. Pick up and run casing hanger. Change out upper rams to 5.5 inch. Rig up test equipment and pressure test upper rams to 250 low psi and 3500 high psi for five minutes. Rig down test equipment. Rid down elevators and elevator links. Clean rig floor and prep for casing run. Preparing to have a pre job safety meeting with casing crew. Falls Creek #6 7 3 GEOLOGICAL DATA 3.1 Lithostratigraphy Tops by Hilcorp Alaska, LLC. Geologist. PROGNOSED OBSERVED FORMATION MD (ft) TVD (ft) SSTVD (ft) MD (ft) TVD (ft) SSTVD (ft) Beluga 135 5461 4906 -4716 5322 4982 -4715 Top Tyonek 5748 5159 -4969 5600 5235 -4969 T-8 6566 5882 -5692 6422 5983 -5716 T-10 6885 6164 -5974 6700 6236 -5969 T-50 8229 7448 -7258 8157 7555 -7288 T-60 8463 7671 -7481 8372 7738 -7471 T-65 8886 8075 -7885 8855 8125 -7858 3.2 Lithology Details Full service mudlogging began at 3530’ MD/ 3345.67’ TVD. All the sample lithology descriptions provided by Canrig began after the surface casing point. The well includes Sterling, Beluga and Tyonek formations. The basic building blocks in this depositional area have a unique lithology of thick structured formations of tuffaceous sediments. These fluvial deposits are of tuffaceous claystone, tuffaceous siltstone, tuffaceous sandstones, and lose disaggregated, unconsolidated sands. The ash and tuff are revealed along with devitrified volcanic glasses as loosely (friable) to heavily indurated clasts of volcanic origin. TUFFACEOUS CLAYSTONE (3530' - 3575') = Medium gray to dark gray with green and slight dark black hues; soft to malleable; irregular fracture with slumped rounded cuttings when hydrated and shaped by bit action; smooth to tuffaceous claystone (3530' - 3575') slight waxy shiny luster; overall thick structure; with tuffaceous siltstone and loose unconsolidated sands entrained. SAND, TUFFACEOUS SILTSTONE (3575' - 3620') = Loose unconsolidated sands poorly sorted of lower fine to upper coarse grains; dominantly quartz entrain with tuffaceous siltstone, tuffaceous claystone, and coal; coal clasts very small indicating a thin stringer; sands rounded to subangular; fair sphericity. SAND (3620' - 3690') = Dominantly quartz with accessories of tuffaceous claystone, siltstone and clasts of coal; poorly sorted, very fine upper to lower very coarse grain size; angular to subrounded; low to fair sphericity; etching and conchoidal caving on quartz surfaces; trace sandstones with weak matrix cements; unconsolidated sands are texturally immature; sands are interbedded with equally large bodies of tuffaceous claystone and tuffaceous siltstone. TUFFACEOUS CLAYSTONE / TUFFACEOUS SILTSTONE (3690' - 3775') = Medium gray to dark gray Falls Creek #6 8 with black and green hues; tuffaceous claystone and siltstone have matrixes of volcanic tuff, ash and devitrified glass; none responsive to HCl; tuffaceous claystone is weakly cohesive and moderately adhesive; tuffaceous siltstone is gritty with thick basal structure; both tuffaceous claystone and siltstones are soft to malleable and occasionally crumbly; irregular fracture and rounded slumped cuttings are due to hydrated with mud and bit action; dull earthy to slight shiny luster when wet. SAND (3790' - 3865') = Translucent clear to colored dirty grayish white opaque with upper fine to lower coarse grain clasts of tuffaceous siltstone, black carbonaceous materials, and trace sandstone clasts; loose unconsolidated sands are interbedded with claystones, siltstones, coals in sandstone sized grains; angular to sub angular to subrounded with low to fair sphericity; textural maturity is young showing surface etching and conchoidal caving. TUFFACEOUS CLAYSTONE/TUFFACEOUS SILTSTONE (3865' - 3925') = Medium gray to dark gray with black hues; soft malleable consistency in claystone and firmer to crumbly tenacity in tuffaceous siltstone; fracture for both is irregular; cuttings are slumped to rounded to wedge like; smooth claystone to gritty tuffaceous siltstone; thick overall basal structure; trace of small coal stringers are present. SAND (3925' - 3980') = Translucent to dirty grayish white opaque with overall medium gray color; moderately sorted with upper fine to upper medium grain with trace lower coarse grains; fair sphericity with subangular to rounded poor to unconsolidated; impact surface features common; secondary silt and carbonaceous material. TUFFACEOUS SILTSTONE/TUFFACEOUS CLAYSTONE (3980' - 4050') = Medium gray to medium dark gray; firm to friable; poor to moderate induration; dense to crumbly tenacity; irregular fracture; nodular to wedgelike cuttings habit; dull to earthy luster; silty to gritty texture; massive structure with occasional interbedded upper fine to lower medium grained sand; sand is quartz dominant with secondary carbonaceous material; tuffaceous claystone is highly cohesive with a mushy consistency. TUFFACEOUS CLAYSTONE/TUFFACEOUS SILTSTONE (4050' - 4110') = Medium gray to medium dark gray; soft to slightly firm; malleable to slightly elastic tenacity; earthy fracture; massive to nodular cuttings habit; dull luster; dominantly massive structure with interbedded sand and rare micro- lamination of carbonaceous material; clay is cohesive and expansive with a pasty consistency. TUFFACEOUS SILTSTONE (4110' - 4160') = Medium gray to dark gray; dense to brittle tenacity; blocky to irregular fracture; nodular cuttings habit; occasional PDC bit deformation; dull to earthy luster; silty to gritty texture; massive structure; abundant coal; secondary sand. SAND/TUFFACEOUS SILTSTONE (4160' - 4220') = Translucent quartz grains with secondary grayish black lithic fragments; upper fine to upper very fine grained; moderate to high sphericity; subangular to angular grains; moderate to well sorted; unconsolidated to poorly consolidated; silty matrix material; grain supported; texturally submature; compositionally immature; secondary tuffaceous siltstone; trace devitrified ash. SANDSTONE/TUFFACEOUS SILTSTONE (4220' - 4280') = Medium dark gray to dark gray; mixed quartz and lithic framework; upper very fine to upper fine grained; moderate to low sphericity; subangular to angular; moderate sorting; moderately to well consolidated; hard; grain supported; slight foliation; occasional to rare planar fracture; trace carbonaceous material and tuff; rare biotite mica. TUFFACEOUS SILTSTONE (4280' - 4350') = Medium gray to medium dark gray; firm to easily friable; moderate induration; dense to pulverulent tenacity; irregular to blocky fracture with occasional planar fracture; massive to nodular cuttings habit with secondary PDC bit markings; dull to earthy luster; silty to gritty texture; massive structure with occasional micro lamination; secondary tuffaceous claystone containing mixed lithic sand. Falls Creek #6 9 TUFFACEOUS SILTSTONE (4350' - 4410') = Medium light gray to medium dark gray; firm to easily friable; moderate to poor induration; dense to pulverulent tenacity; blocky irregular fracture; nodular cuttings habit with occasional PDC bit markings; earthy luster; smooth to silty texture; massive structure; secondary lower fine grained sand composed of quartz, carbonaceous material and trace volcanic material. TUFFACEOUS CLAYSTONE (4410' - 4470') = Medium gray; soft to slightly firm; very poor induration; malleable tenacity; irregular to earthy fracture; massive to nodular cuttings habit; dull to earthy luster; gritty texture; massive structure; cohesive and colloidal; pasty to tacky consistency; secondary tuffaceous siltstone with occasional fissility; secondary sand and carbonaceous material. TUFFACEOUS CLAYSTONE / SAND (4470' - 4550') = Dark gray to medium gray; soft to slightly firm; very poor induration; malleable to elastic tenacity; irregular to earthy fracture; massive to nodular cuttings habit; dull to earthy luster; gritty texture; massive structure; cohesive and colloidal; pasty to tacky consistency; sand: upper fine to lower medium grained; moderate sphericity; sub- angular to subrounded; moderate to well sorted; well consolidated to unconsolidated; grain supported; quartz and mixed lithic framework. TUFFACEOUS SILTSTONE/TUFFACEOUS CLAYSTONE (4550' - 4610') = Medium gray to medium dark gray; firm to easily friable; moderate induration; dense to crumbly tenacity; irregular to blocky fracture with rare planar fracture; massive to nodular cuttings habit with trace PDC bit markings; dull to earthy luster; silty to gritty texture; massive structure claystone is slightly adhesive, non- cohesive with a punky consistency. TUFFACEOUS SILTSTONE (4610' - 4690') = Medium gray to dark gray; firm to friable; moderate induration; dense tenacity; nodular to wedgelike cuttings habit; silty to slightly gritty texture; dull luster; irregular fracture; dominantly massive structure; second non-tuffaceous siltstone: dark gray to brownish black; soft to easily friable; poor to moderate induration; brittle to crumbly tenacity; planar fracture; wedgelike to tabular cuttings habit; earthy luster; silty to gritty texture; slight micro lamination; secondary carbonaceous material. TUFFACEOUS SILTSTONE (4690' - 4770') = Medium light gray to dark gray; firm to easily friable; moderate to poor induration; dense to pulverulent tenacity; blocky irregular fracture; nodular cuttings habit with rare PDC bit markings; earthy luster; smooth to silty texture; massive structure; secondary tuffaceous sandstone; medium dark gray to grayish black; upper very fine to lower fine grained; poor sphericity; subrounded to subangular; friable to moderately consolidated; mixed dark lithic and quartz framework. TUFFACEOUS CLAYSTONE (4770' - 4840') = Medium gray to medium dark gray; soft; poorly indurated; dense to malleable tenacity; earth fracture; massive to nodular cuttings habit; dull luster; clayey to silty texture; massive structure with occasional micro- laminations of carbonaceous material; cohesive and colloidal; pasty to tacky consistency; abundant tuffaceous siltstone; secondary carbonaceous material and tuffaceous sandstone. TUFFACEOUS CLAYSTONE (4840' - 4890') = Medium light gray to medium dark gray; soft; poor induration; malleable tenacity; irregular to earthy fracture; nodular cuttings habit; dull to earthy luster; silty to clayey texture; massive structure; cohesive and adhesive; tacky consistency; abundant tuffaceous siltstone; secondary siltstone and fine grained sand. SAND (4890' - 4965') = Overall medium gray color; mixed quartz and sand sized clasts of tuffaceous siltstone and carbonaceous material, coal and soft hydrated tuffaceous claystone; well sorted of upper fine to lower medium grain size; subangular to subrounded with fair to moderate sphericity; sands are unconsolidated with a moderate textural maturity; surface etching and conchoidal caving; visible degassing on coal clasts; trace clasts of a dark sandstone; heavily indurated with a strong matrix cement not responsive to HCl. Falls Creek #6 10 SAND (4965' - 5035') = Mixed none homogeneous unconsolidated sands of quartz, tuffaceous siltstone, carbon material, coal and tuffaceous claystone; lower fine to upper medium grain size; poor to fair sorted; moderate sphericity and subrounded grains; moderate textural maturity; some surface etching and conchoidal caving. SAND/SANDSTONE (5035' - 5160') = Dark medium gray color; quartz clasts translucent to dry grayish white to black color; poorly sorted from very fine to upper coarse grains; angular to subrounded grains with low to fair sphericity; young textural maturity; loose unconsolidated sands are composed quartz and sand sized clasts of tuffaceous siltstone, black carbonaceous materials, trace calcite and biotite and interbedded with sandstone; the sandstone is heavily indurated with a tight visual porosity; grain supported and a matrix cement none reactive to HCl with individual quartz grains fine to lower medium grain size; interbedded through is thinly structured shards of coal with visible degassing; indicating a loose chambered structure. SAND/SANDSTONE (5160' - 5260') = Loose unconsolidated sands interbedded with tight to loose sandstone and tuffaceous claystone; sands entrained in tuffaceous claystone possibly due to bit action; thinly bedded stringers of coal, black carbonaceous shale and black carbon material grading to carbonaceous shale or coal; sandstones are loosely indurate and entrained in tuffaceous claystone; the hydrated tuffaceous claystone is due to the mud and bit action; overall color of sands is medium gray of a poorly sorted lower fine to upper very coarse with subangular to subrounded grains; black carbonaceous material, black and brown carbonaceous shale and shards of coal are entrained by the hydrated tuffaceous claystone. TUFFACEOUS SILTSTONE (5260' - 5330') = Medium dark gray to dark gray; soft to friable; low degree of induration; dense to crumbly tenacity; irregular fracture with occasional planar fracture nodular to blocky cuttings habit; dull luster; clayey to silty texture; massive structure; secondary very fine grained sandstone with variable hardness from soft to moderately firm; trace micro lamination of carbonaceous material; trace lower fine grained sand and tuff. TUFFACEOUS SILTSTONE/SANDSTONE (3530' - 5425') = Tuffaceous siltstone is medium gray to dark gray; soft to firm friable; moderate induration; dense to brittle pulverulent tenacity; irregular fracture and occasional planar fracture; massive to nodular cuttings habit with occasional PDC bit markings; dull luster; silt to clayey texture; massive structure; sandstone is upper very fine to upper fine grained; clasts are subround to subangular; moderate sphericity; grains supported with trace tuffaceous matrix; hardness ranges from hard to friable; abundant carbonaceous material; abundant tuffaceous claystone; safe carb mud additive present. SAND/TUFFACEOUS SILTSTONE (5425' - 5515') = Translucent quartz grains to grayish black carbonaceous fragments; lower to upper fine grained; moderate sphericity; angular to subangular; well sorted; unconsolidated to poorly consolidated; trace silt to tuffaceous matrix; siltstone is medium dark gray; easily friable; poor induration; dense to pulverulent tenacity; irregular fracture with secondary planar fracture; nodular cuttings habit with rare PDC bit deformation; dull luster; silty to gritty texture; massive structure; secondary tuffaceous claystone; abundant coal and carbonaceous material in 5490' sample. TUFFACEOUS SILTSTONE/TUFFACEOUS SANDSTONE (5515' - 5630') = Medium dark gray to dark gray; firm to friable; low to moderate degree of induration; dense to crumbly tenacity; irregular fracture with occasional planar fracture nodular to blocky cuttings habit; dull luster; clayey to silty texture; massive structure with occasional micro laminations of carbonaceous material; tuffaceous sandstone dominant 5550' sample; light gray to light bluish gray; quartz framework with secondary grayish black lithics; lower to upper fine grained; well sorted; angular to subrounded; moderate sphericity; unconsolidated to soft and moderately hard in part; abundant tuffaceous matrix material; grain supported; free tuff common; secondary tuffaceous claystone and carbonaceous material. Falls Creek #6 11 TUFFACEOUS SILTSTONE (5630' -5685') = Medium gray to medium dark gray; poor to moderate induration; soft to friable; dense to brittle; irregular to blocky fracture; massive cuttings habit with clear PDC bit markings; dull luster; silty to gritty texture; massive structure; secondary sand: upper to lower fine grained; becomes moderately consolidated tuffaceous sandstone in deeper samples. TUFFACEOUS CLAYSTONE / TUFFACEOUS SANDSTONE (5685' - 5770') = Medium light gray to medium dark gray; soft; malleable tenacity; irregular fracture; massive to nodular cuttings habit; dull luster; clayey to gritty texture; massive structure; tuffaceous sandstone: medium gray to medium light gray; quartz dominant framework with secondary volcanics and carbonaceous material; upper very fine to lower fine grained; well sorted; angular to subangular; moderate sphericity; friable to firm friable; tuffaceous, silty matrix material; grain supported; secondary tuffaceous siltstone. TUFFACEOUS SILTSTONE / TUFFACEOUS SANDSTONE (5770' - 5850') = Medium dark gray to dark gray; firm; poor to moderate induration; dense to pulverulent tenacity; irregular fracture; massive to platy cuttings habit; dull luster; silty to gritty texture; massive structure; tuffaceous sandstone: upper very fine to lower fine grained; quartz and mixed lithic framework; well sorted; subrounded to subangular; moderate sphericity; friable to moderately hard; grain supported; tuffaceous matrix; secondary unconsolidated sand. TUFFACEOUS SILTSTONE / SAND (5850' - 5930') = Medium dark gray to dark gray; firm to moderately hard; moderately indurated; dense to tough tenacity; irregular fracture; platy to nodular cuttings habit; dull luster; smooth to gritty texture; massive structure; sand: quartz dominant framework with secondary mixed lithics; upper very fine to upper fine grained; well sorted; angular to subangular; moderate sphericity; unconsolidated to poorly consolidated; secondary tuffaceous claystone and tuffaceous sandstone; trace carbonaceous material. TUFFACEOUS SANDSTONE (5930' - 5980') = Medium light gray to medium gray; lower fine to upper fine grained; moderate sphericity; subangular to subrounded; well sorted; poorly consolidated to unconsolidated; tuffaceous matrix material; grain supported; abundant volcanic tuff; secondary coal. SAND / TUFFACEOUS SANDSTONE (5980' - 6090') = Loose unconsolidated sands dominantly quartz; upper very fine to lower medium grains; fair sorted and subangular to round; fair to high sphericity; evidence of surface etching and conchoidal caving; tuffaceous sandstone is dominantly grain supported with a matrix of volcanic ash, tuff, and occasional devitrified glass; none reactive to HCl; heavily indurated to weakly cemented clasts with the higher visual porosity tuffaceous sandstones are easily sheared; dominantly grain supported clasts that have a low visual porosity are heavily indurated clasts; topical appearance is a salt and pepper, a light and dark due to the translucent quartz and the inclusion of darker black carbon materials in the sandstone matrices. SAND / TUFFACEOUS SANDSTONE ( 6090' - 6195') = Overall medium gray color individual quartz clasts are translucent to dirty grayish white opaque color; fair sorted; upper fine to lower medium grain size; low to fair sphericity; textural maturity is well aged; tuffaceous sandstone matrix cement is composed of volcanic ash, tuff and sometimes seen devitrified glass; none reactive to HCl; well indurated with a low to fair visual porosity; occasional hydrated clasts are easily sheared being weakly cemented; black carbonaceous material found through the sandstones. TUFFACEOUS SANDSTONE (6195' - 6290') = Medium gray to a salt and pepper appearance due to inclusions of black carbon material through the tuffaceous sandstone cuttings; grain supported dominantly quartz with black carbon materials held in a volcanic ash, tuff matrix; strongly indurated to weakly cemented with strong to moderate visual porosity seen when sandstone clasts hydrated; matrix cement none reactive to HCl; quartz is clear translucent to dirty grayish white with subangular to subrounded clasts; low to fair sphericity with well aged moderate textural maturity; thinly bedded stringers of coal held entrained with tuffaceous sandstones. TUFFACEOUS SANDSTONE (6290' - 6350') = A salt and pepper appearance of light an dark bands due Falls Creek #6 12 to black carbon materials included in a strongly indurated volcanic ash and tuff matrix cement with quartz grains of fine to lower medium grain size with subangular to subrounded and fair to moderate sphericity; well sorted grading to well worked aged textural maturity; entrained cuttings of coal still degassing; volcanic tuff scattered through out as boundary included in cuttings of tuffaceous siltstone and sandstone SANDSTONE / TUFFACEOUS SANDSTONE (6350' - 6455') = Medium gray to dark gray; quartz, carbonaceous material and mixed lithic framework; upper very fine to lower fine grained; well sorted; subangular to subrounded; moderate sphericity; friable to hard; grain supported; massive structure; occasional silty matrix to no matrix; tuffaceous sandstone is light gray to medium gray with salt and pepper appearance; lower to upper fine grained; well sorted; subangular; moderate sphericity; polished surface features; poor to moderate consolidation; secondary tuffaceous siltstone; trace upper medium subangular quartz grains. TUFFACEOUS SANDSTONE (6455' - 6510') = Medium gray to medium light gray; quartz framework with secondary volcanics and carbonaceous material; upper very fine to lower fine grained well sorted; subangular to subrounded; moderate sphericity; polished surface features; moderately hard; grain supported; abundant tuffaceous matrix and free tuff. TUFFACEOUS SILTSTONE (6510' - 6570') = Medium gray to medium dark gray; firm to moderately hard; moderately to well indurated; dense to brittle tenacity; irregular fracture; nodular to wedgelike cuttings habit; dull luster; silty to smooth texture; massive structure; secondary tuffaceous sandstone and carbonaceous material; trace volcanic tan fragments. TUFFACEOUS SANDSTONE (6570' - 6630') = Medium gray to medium light gray; quartz framework with secondary volcanics, carbonaceous material and mixed lithics; upper very fine to lower fine grained; well sorted; subangular to subrounded; moderate sphericity; polished surface features; moderately hard; grain supported; abundant tuffaceous matrix; abundant tuffaceous siltstone and carbonaceous material. TUFFACEOUS SILTSTONE / SANDSTONE (6630' - 6710') = Medium dark gray to dark gray; firm to moderately hard; moderately indurated; dense to crumbly tenacity; irregular fracture; platy cuttings habit with clear PDC bit markings; dull luster; smooth to gritty texture; massive structure; sandstone: lower very fine to upper very fine grained; quartz framework with carbonaceous material present in micro laminations; well sorted; subangular; moderate sphericity; moderately hard to hard; visually good porosity and permeability. TUFFACEOUS SILTSTONE (6710' - 6760') = Medium dark gray to brownish gray; firm to friable; moderate induration; dense tenacity; irregular fracture; nodular to scaly cuttings habit with PDC bit markings; dull luster; smooth to gritty texture; massive structure; secondary tuffaceous sandstone; trace carbonaceous material. TUFFACEOUS SANDSTONE (6760' - 6810') = Medium gray to medium light gray; quartz framework with secondary volcanics and carbonaceous material; upper very fine to lower fine grained well sorted; subangular to subrounded; moderate sphericity; polished surface features; moderately hard to friable; grain supported; abundant tuffaceous matrix; abundant coal. TUFFACEOUS SILTSTONE / TUFFACEOUS SANDSTONE (6810' - 6905') = Medium light gray to dark gray; firm friable; moderate degree of induration; dense tenacity; irregular fracture; scaly to nodular cuttings habit; dull luster; silty to gritty texture; massive structure; tuffaceous sandstone: quartz dominant framework with volcanics and carbonaceous material; medium light gray to brownish gray; lower very fine to lower fine grained; well sorted; subrounded to subangular; moderate sphericity; occasional polished surface features; grain supported; variable amounts of tuffaceous matrix material; secondary coal and carbonaceous material. TUFFACEOUS SANDSTONE (6905' - 6960') = Medium light gray to medium dark gray; quartz framework Falls Creek #6 13 with volcanics and carbonaceous material; lower to upper fine grained; well sorted; subangular to subrounded; moderate to high sphericity; polished surface features; soft to easily friable; grain supported; abundant tuffaceous matrix; secondary tuffaceous siltstone and sand. TUFFACEOUS SANDSTONE (6960' - 7050') = Overall bright, light, grayish white sandstone in grain supported sandstone composed of volcanic ash, tuff and occasional evidence of devitrified glass with trace black carbon material in the matrix cement of the sandstone; none reactive to HCl; visually moderate tight sandstone with low to fair porosity; well sorted with upper fine to lower medium grain size; subrounded to round with moderate sphericity; entrained with the sandstone is coal in a thick structure; no visible degassing. COAL (7040' - 7056') = Matte black to vitreous shiny black color; firm brittle tenacity; splintery to wedge like to blocky cuttings with irregular to parallel fracture; seemly smooth to slight rough texture due to the exposure of rounded broken laminae exposed on the axial perpendicular sides of the coal clasts; no degassing or evident sign of shear stress in coal cuttings. TUFFACEOUS SANDSTONE (7056' - 7180') = Overall light grayish white to slightly darker grayish white with black carbon streaks in the matrix to grains support tuffaceous sandstone; none reactive matrix composed of volcanic ash, tuff and occasional devitrified glass; fair sorted grains of subrounded to round with fair to high sphericity and well aged textural maturity; entrained in the sandstone is tuffaceous siltstone and coal clasts; visible degassing in coals; dominantly quartz grains submerged in tuffaceous moderately cemented matrix with coal streaks due to bit action. TUFFACEOUS SANDSTONE (7180' - 7225') = Dominantly a matrix supported sandstone; large quantities of volcanic ash, tuff with quartz grains of upper fine to lower medium grain size; high visual porosity due to weak cemented sandstone with trace coals and tuffaceous siltstone. TUFFACEOUS SANDSTONE (7225' - 7315') = Translucent to dirty grayish white grain color; well sorted with subrounded and fair to high sphericity; well aged textural maturity; trace pieces of tuff scattered though out; matrix cement volcanic ash and tuff; none reactive to HCl; trace black steaks in sandstone due to bit action and included black carbon material in sandstone matrix; dominantly quartz in tuffaceous sandstones; grains are upper fine to upper medium with trace in lower coarse. TUFFACEOUS SANDSTONE (7315' - 7385') = Overall light gray color for tuffaceous sandstone; becoming matrix supported; subrounded to round grains in matrix cement; grains are upper fine to upper medium grain size with a scattering of larger clast of upper coarse to upper very coarse grain size; matrix cement is weakly cemented when hydrated by mud and bit action; traces of a darker tuffaceous sandstone appear with a tough high induration; a very tight visual porosity and strongly cemented. TUFFACEOUS SANDSTONE (7385' - 7450') = Dirty grayish white overall color; matrix supported; with upper fine to lower medium grain size; well sorted with fair to moderate sphericity; textural maturity is well aged; matrix is composed of volcanic ash and tuff and devitrified glass is in evidence; clasts of coal are entrained with sandstone; coals are visibly degassing; larger clasts of coal are signs of popping of the walls from above. TUFFACEOUS SANDSTONE (7450' - 7515') = Matrix supported sandstone clasts; due to bit action and mud the sandstone clasts are hydrated and soften; weakly cements and lightly indurated; subangular to subrounded grains found in matrix cement; fine upper to medium lower grain size; fair t moderate sphericity; well sorted; well aged textural maturity; matrix cement is volcanic ash and tuff with evidence of devitrified glass. TUFFACEOUS SANDSTONE (7515' - 7560') = Grayish white with black streaks due to bit action in a matrix supported with subround to round fine upper to lower medium grains size; well sorted, fair to moderate sphericity; mature textural maturity; weakly cemented with poor visual porosity. Falls Creek #6 14 TUFFACEOUS SILTSTONE (7560' - 7610') = Medium gray to medium dark gray; firm to friable; moderately to well indurated; tough to brittle tenacity; irregular fracture; massive cuttings scaly to tabular cuttings habit; dull luster; silty to gritty texture; massive structure; secondary tuffaceous sandstone. TUFFACEOUS SILTSTONE / TUFFACEOUS SANDSTONE (7610' - 7710') = Medium dark gray to dark gray with secondary brownish gray; firm to friable; moderately indurated; dense to crumbly tenacity; irregular fracture; platy to scaly cuttings habit; dull luster; smooth to gritty texture; massive structure with secondary microlamina; tuffaceous sandstone: quartz dominant framework with carbonaceous material and volcanics; carbonaceous material occasionally appears in thin seams; lower medium to upper very fine grained; moderately sorted to well sorted; subangular to angular; moderate sphericity; polished surface features common with higher tuffaceous content; hard to friable; grain supported. TUFFACEOUS SANDSTONE (7710' - 7770') = Medium light gray to medium dark gray; quartz framework with volcanics and carbonaceous material; lower to upper fine grained; well sorted; subangular to subrounded; moderate to high sphericity; polished surface features; soft to easily friable; grain supported; abundant tuffaceous matrix; secondary tuffaceous siltstone and sand. COAL (7770' - 7820') = Black to blackish gray; hard; well indurated; tough pulverulent tenacity; conchoidal to blocky fracture; fine blocky cuttings habit; vitreous luster; smooth to matte texture; massive structure with occasional thin laminae; sub bituminous in appearance; coal is degassing; secondary tuffaceous sandstone. TUFFACEOUS SANDSTONE / TUFFACEOUS SILTSTONE (7820' - 7910') = Medium light gray to medium gray; dominant quartz framework with volcanics and carbonaceous material; lower very fine to lower fine grained; well sorted; subrounded to subangular; moderate sphericity; occasional polished surface features; grain supported; variable amounts of tuffaceous matrix material; tuffaceous siltstone: medium light gray to dark gray with brownish gray hues; firm friable; moderate degree of induration; dense tenacity; irregular fracture; scaly to nodular cuttings habit; dull luster; silty to gritty texture; massive structure; material. TUFFACEOUS SILTSTONE (7910' - 7980') = Medium dark gray to dark gray with brownish gray hues; firm to easily friable; moderate to poor induration; dense to crumbly tenacity; irregular with occasional planar fracture; nodular to scaly cuttings habit with common PDC bit markings; silty to gritty texture with very fine grained sand present; massive structure; tuffaceous material common in siltstone fragments; secondary tuffaceous sandstone; carbonaceous material present. TUFFACEOUS SANDSTONE (7980' - 8030') = Quartz framework with secondary carbonaceous material; lower fine to lower medium grained; moderate to well sorted; subangular to subrounded; moderate sphericity; moderately hard to soft; grain supported; tuffaceous matrix; trace very coarse quartz grains; abundant loose sand in sample. TUFFACEOUS SILTSTONE (8030' - 8095') = Medium gray to brownish gray; friable to moderately hard; moderately indurated; crumbly to pulverulent tenacity; irregular to occasional planar fracture due to PDC bit markings; nodular cuttings habit; dull to slightly waxy luster; gritty texture; massive structure; sand common within siltstone cuttings; abundant tuffaceous sandstone. TUFFACEOUS SANDSTONE (8130' - 8160') = Medium light gray to medium dark gray with salt and pepper appearance; quartz dominant framework with secondary volcanic fragments and carbonaceous material; lower to upper very fine grained; moderately sorted; subangular to subrounded; moderate sphericity; occasional PDC bit markings; friable to firm; grain supported to matrix supported in part; tuffaceous and silty matrix material. COAL (8160' - 8190') = Black to grayish black; moderately hard; moderate degree of induration; brittle Falls Creek #6 15 tenacity; blocky to conchoidal fracture; blocky cuttings habit; vitreous luster; smooth to matte texture; massive structure; sub-bituminous; no apparent degassing. TUFFACEOUS SILTSTONE (8190' - 8260') = Medium gray to medium dark gray; friable to moderately hard; moderate degree of induration; crumbly to tough tenacity; irregular fracture with occasional planar fracture due to PDC bit deformation; tabular to platy cuttings habit; dull luster; gritty to abrasive texture; massive structure with occasional micro lamination of carbonaceous material; secondary tuffaceous sandstone and sand. TUFFACEOUS SANDSTONE / TUFFACEOUS (8260' - 8350') = Medium gray to dark gray with a speckled appearance; quartz framework with volcanics and carbonaceous material; upper very fine to upper fine grained; moderately sorted; subangular; moderate sphericity; soft to firm; grain supported; tuffaceous matrix with clay and silt; tuffaceous siltstone: medium dark gray; firm to moderately hard; moderate induration; dense to pulverulent tenacity; irregular fracture; nodular to scaly cuttings habit; PDC bit markings present; dull luster; gritty to smooth texture; massive structure; secondary volcanics and carbonaceous material. TUFFACEOUS SILTSTONE (8350' - 8400') = Medium dark gray with brownish hues; soft to firm friable; moderate degree of induration; dense to pulverulent; irregular fracture; nodular to blocky cuttings habit; dull to earthy luster; smooth clayey texture; massive structure; slightly cohesive showing increased clay content. TUFFACEOUS SANDSTONE (8400' - 8530') Light gray to medium gray overall color; matrix supported tuffaceous sandstone with matrix cement composed of volcanic ash, tuff, and visibly seen devitrified volcanic glass; matrix cement none reactive to HCl; dominantly quartz well sorted of lower fine to lower medium grain size carried within the tuffaceous matrix cement; visible black streaks seen on the sandstone surfaces are black carbon materials so cut by bit action; quartz grains are subround t round with moderate to high sphericity; high well aged textural maturity; matrix cement when hydrated by mud and is weakly indurated. TUFFACEOUS SANDSTONE (8530' - 8580') = Overall color change; sandstone are slightly light to dark brownish gray color; darker tuffaceous sandstones are firmer, tougher to shear; matrix cement none reactive to HCl; well sorted with upper very fine to lower fine grain size; moderate sphericity; overall an aged textural maturity. TUFFACEOUS SILTSTONE (8580' - 8635') = Overall medium dark brownish gray color; crumbly tenacity; irregular fracture with rounded blocky cuttings; gritty texture; overall thick basal structure; slight shiny luster due to devitrified volcanic glass; evidence of coal and carbonaceous material adhering to siltstone cuttings; interbedded with sand and sandstone and trace coals. TUFFACEOUS SANDSTONE (8635' - 8700') = Light gray to dark gray with light brown to darker brown hues; light grayish brown tuffaceous sandstone is weakly cemented and indurated; the darker brown sandstone is heavily indurated with a similar tuffaceous matrix cement but strongly bonded matrix between cement and sandstone grains; light matrix cement none reactive to HCl; darker matrix cemented sandstone slightly reactive to HCl as in dolomitic slow reactions. SAND/TUFFACEOUS SANDSTONE (8700' - 8770') = Matrix supported light grayish white sandstone and loose unconsolidated sands; sands poorly sorted with angular to subrounded grains of lower fine to upper very coarse grains of 1 to 2 mm diameter; dominantly translucent clear to bright white opaque color; low or young textural maturity in loose sands; sandstones are well sorted of low fine to upper medium grain size; sandstone grains are subangular to subround; poor to low sphericity. SAND / TUFFACEOUS SANDSTONE (8770' - 8885') = Overall medium to dark gray with strong brown hues; loose sands disaggregated interbedded with larger tuffaceous sandstone beds; overall quartz are Falls Creek #6 16 well sorted; lower very fine to lower medium grain size; subrounded with fair to moderate sphericity; sands and sandstones are moderate to high textural maturity; tuffaceous sandstone is composed of weakly to strong bonded volcanic ash and tuff; none reactive to HCl in the lighter sandstone with more induration and tighter visual porosity in the darker brown tuffaceous sandstones; black carbon materials found in all sandstones along with scattered shales and tuffs. SAND/TUFFACEOUS SANDSTONE (8885' - 8975') = Light with darker black streaks due to bit action; dominantly matrix cement to lesser grain supported tuffaceous sandstone clasts; poorly indurated and weakly cemented; overall grain size is very fine lower to fine upper; fair to moderately sphericity; subangular to rounded grains; loose dissagregated sands are very fine lower to lower fine grain; well sorted; sub rounded to rounded; traces of shales and tuff scattered through out; good visual porosity in the tuffaceous sandstones; visible degassing from thin stringers of coal interbedded with the sand and tuffaceous sandstones. TUFFACEOUS SANDSTONE (8795' - 9060') = Light gray to medium dark gray; upper fine to lower medium grained; quartz dominant framework with carbonaceous material and volcanics; moderately to well sorted; subangular to subrounded; moderate to high sphericity; firm to unconsolidated; grain supported; tuffaceous to silty matrix material; secondary tuffaceous siltstone and carbonaceous material. Falls Creek #6 17 3.3 Sampling Program The sampling program, specified by the Hilcorp Geologist called for the collection of two sets of Washed and Dried Reference Samples beginning at 3540’ MD. The resulting set, interval, and distribution are shown below. Sets Type and Purpose Interval Frequency Distribution A Washed and Dried Reference Samples 3510’ – 4890’ 4890’ – 6300’ 6300’ – 7800’ 7800’ – 9060’ 30’ 30’ 30’ 30’ David Buthman Hilcorp Alaska LLC 3800 Center Point Drive, Suite 100 Anchorage, AK 99508 B Washed and Dried Reference Samples 3510’ – 4890’ 4890’ – 6300’ 6300’ – 7800’ 7800’ – 9060’ 30’ 30’ 30’ 30’ David Buthman Hilcorp Alaska LLC 3800 Center Point Drive, Suite 100 Anchorage, AK 99508 Falls Creek #6 18 4 DRILLING DATA 4.1 Surveys Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 18.50 0.00 0.00 18.50 0.00 0.00 0.00 0.00 128.78 1.51 36.52 128.77 1.17 0.87 0.70 1.37 189.23 1.65 29.20 189.19 2.57 1.77 1.60 0.40 253.40 1.46 44.72 253.34 3.96 2.79 2.43 0.72 313.57 2.35 31.11 313.48 5.56 3.97 3.39 1.65 376.51 3.10 20.46 376.35 8.27 5.23 5.31 1.43 438.81 3.07 10.99 438.56 11.48 6.14 7.86 0.82 501.96 3.47 356.77 501.60 15.05 6.36 11.01 1.43 561.24 3.81 342.07 560.77 18.72 5.65 14.63 1.66 621.43 4.21 333.69 620.81 22.60 4.06 18.82 1.18 681.18 4.49 337.64 680.39 26.73 2.20 23.35 0.70 742.13 5.30 328.58 741.11 31.34 -0.18 28.53 1.83 804.91 5.51 329.93 803.62 36.42 -3.20 34.41 0.39 868.42 5.70 326.41 866.82 41.68 -6.47 40.57 0.62 931.67 5.79 322.95 929.75 46.85 -10.13 46.78 0.57 992.82 6.35 332.99 990.56 52.32 -13.53 53.18 1.96 1056.79 7.22 326.46 1054.09 58.83 -17.36 60.69 1.81 1119.41 7.82 325.20 1116.17 65.61 -21.96 68.78 0.99 1182.58 8.69 325.65 1178.68 73.08 -27.11 77.71 1.38 1245.71 9.30 327.68 1241.03 81.32 -32.53 87.47 1.08 1308.46 10.00 326.63 1302.90 90.16 -38.23 97.88 1.16 1371.30 11.62 326.00 1364.62 99.96 -44.78 109.53 2.58 1434.07 13.98 326.30 1425.82 111.51 -52.52 123.26 3.76 1497.57 15.63 326.78 1487.22 125.05 -61.46 139.29 2.60 1561.80 17.27 328.41 1548.82 140.41 -71.19 157.32 2.65 1624.66 19.39 329.83 1608.48 157.38 -81.33 176.97 3.46 1688.01 21.24 330.54 1667.89 176.46 -92.26 198.88 2.95 1751.16 23.20 332.99 1726.35 197.51 -103.53 222.71 3.43 1814.38 24.42 334.58 1784.19 220.41 -114.80 248.23 2.18 1877.45 23.87 335.07 1841.74 243.76 -125.78 274.03 0.93 1941.03 24.82 334.47 1899.66 267.47 -136.95 300.23 1.54 2001.11 25.83 334.48 1953.97 290.66 -148.02 325.93 1.68 2067.27 24.96 335.02 2013.74 316.32 -160.13 354.30 1.35 2130.56 25.29 334.75 2071.04 340.65 -171.53 381.17 0.55 Falls Creek #6 19 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 2194.18 24.09 334.67 2128.84 364.68 -182.88 407.75 1.89 2257.43 24.53 335.31 2186.48 388.27 -193.89 433.78 0.80 2320.32 23.65 332.74 2243.90 411.34 -205.12 459.44 2.17 2383.77 23.83 332.66 2301.98 434.04 -216.84 484.95 0.28 2444.33 22.79 333.96 2357.60 455.45 -227.61 508.90 1.90 2507.57 23.05 333.11 2415.84 477.49 -238.59 533.52 0.66 2571.20 23.93 333.68 2474.20 500.17 -249.94 558.87 1.43 2634.72 23.55 333.64 2532.34 523.09 -261.29 584.44 0.59 2698.10 23.75 333.66 2590.40 545.88 -272.58 609.85 0.30 2760.28 25.24 334.39 2646.98 569.05 -283.87 635.62 2.45 2823.91 24.23 334.03 2704.77 593.02 -295.45 662.24 1.61 2886.82 24.05 334.39 2762.18 616.18 -306.64 687.96 0.37 2950.14 24.26 334.02 2819.96 639.51 -317.92 713.87 0.41 3015.02 23.47 333.32 2879.29 663.03 -329.56 740.10 1.29 3077.97 24.49 333.47 2936.81 685.91 -341.01 765.67 1.62 3141.51 25.97 332.36 2994.29 710.02 -353.35 792.73 2.45 3204.71 25.35 334.38 3051.26 734.48 -365.62 820.08 1.70 3268.23 24.12 334.61 3108.95 758.46 -377.06 846.65 1.95 3331.49 24.36 334.12 3166.63 781.88 -388.30 872.62 0.51 3391.46 25.86 334.19 3220.93 804.78 -399.39 898.06 2.49 3455.81 25.73 333.69 3278.87 829.93 -411.69 926.06 0.39 3491.57 25.69 332.81 3311.09 843.79 -418.68 941.56 1.07 3552.59 25.95 333.69 3366.02 867.52 -430.64 968.12 0.76 3616.88 24.83 333.93 3424.10 892.26 -442.80 995.68 1.76 3680.56 24.79 333.22 3481.90 916.18 -454.69 1022.38 0.47 3744.17 24.75 332.30 3539.66 939.87 -466.89 1049.01 0.61 3802.87 24.74 331.56 3592.97 961.55 -478.45 1073.53 0.53 3867.17 24.35 333.75 3651.46 985.27 -490.72 1100.21 1.54 3931.21 23.88 336.20 3709.92 1008.97 -501.79 1126.37 1.73 3995.35 23.91 336.04 3768.56 1032.73 -512.31 1152.34 0.11 4058.86 24.02 335.45 3826.60 1056.24 -522.90 1178.14 0.41 4120.70 23.92 334.85 3883.10 1079.04 -533.46 1203.26 0.42 4185.13 23.79 334.07 3942.03 1102.55 -544.70 1229.32 0.53 4246.14 23.76 333.56 3997.86 1124.62 -555.55 1253.91 0.34 4308.84 23.50 336.04 4055.30 1147.36 -566.25 1279.03 1.64 4371.09 23.35 335.66 4112.42 1169.94 -576.38 1303.78 0.34 2257.43 24.53 335.31 2186.48 388.27 -193.89 433.78 0.80 2320.32 23.65 332.74 2243.90 411.34 -205.12 459.44 2.17 Falls Creek #6 20 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 2383.77 23.83 332.66 2301.98 434.04 -216.84 484.95 0.28 2444.33 22.79 333.96 2357.60 455.45 -227.61 508.90 1.90 4750.43 24.06 333.45 4460.52 1306.10 -641.03 1454.50 0.55 4812.89 23.75 332.58 4517.62 1328.65 -652.52 1479.79 0.75 4876.75 23.54 334.79 4576.12 1351.61 -663.87 1505.39 1.43 4938.56 23.12 333.80 4632.88 1373.66 -674.48 1529.86 0.93 5001.17 23.30 335.43 4690.42 1395.95 -685.06 1554.53 1.06 5064.78 24.18 335.84 4748.65 1419.28 -695.62 1580.14 1.41 5127.77 25.21 335.72 4805.88 1443.28 -706.42 1606.45 1.64 5191.28 25.05 335.38 4863.38 1467.83 -717.58 1633.42 0.34 5253.16 24.41 334.47 4919.59 1491.27 -728.55 1659.30 1.20 5316.43 25.29 334.64 4977.00 1515.28 -739.97 1685.89 1.41 5379.39 24.64 333.97 5034.07 1539.23 -751.49 1712.46 1.14 5441.51 24.24 333.11 5090.63 1562.24 -762.94 1738.15 0.86 5505.17 23.53 332.59 5148.84 1585.18 -774.70 1763.90 1.16 5569.00 24.21 333.85 5207.21 1608.23 -786.33 1789.71 1.32 5632.10 24.87 334.73 5264.61 1631.85 -797.70 1815.91 1.20 5694.29 24.76 334.80 5321.06 1655.45 -808.82 1842.01 0.19 5758.62 24.29 334.76 5379.58 1679.61 -820.20 1868.71 0.73 5822.27 23.44 334.06 5437.79 1702.84 -831.32 1894.46 1.41 5883.93 24.67 333.82 5494.10 1725.41 -842.36 1919.58 1.99 5948.18 24.44 333.34 5552.54 1749.32 -854.24 1946.27 0.47 6011.03 23.73 332.37 5609.91 1772.14 -865.94 1971.89 1.30 6073.03 25.12 332.89 5666.36 1794.91 -877.72 1997.50 2.28 6135.19 24.74 332.65 5722.73 1818.21 -889.71 2023.68 0.64 6199.21 25.40 333.17 5780.72 1842.36 -902.06 2050.79 1.10 6262.86 24.49 332.39 5838.43 1866.24 -914.34 2077.61 1.53 6327.52 25.70 333.89 5896.99 1890.70 -926.72 2105.01 2.11 6390.43 24.90 333.79 5953.86 1914.83 -938.57 2131.88 1.27 6454.02 24.43 332.85 6011.65 1938.54 -950.49 2158.41 0.97 6516.02 24.84 333.32 6068.01 1961.59 -962.18 2184.23 0.73 6579.68 24.44 333.47 6125.87 1985.32 -974.07 2210.76 0.63 6642.78 23.68 332.74 6183.49 2008.26 -985.70 2236.47 1.30 6706.22 24.18 336.53 6241.48 2031.51 -996.71 2262.18 2.55 6768.86 23.65 336.83 6298.74 2054.83 -1006.77 2287.57 0.88 6832.07 24.47 336.03 6356.46 2078.44 -1017.08 2313.33 1.39 6895.40 23.95 335.82 6414.22 2102.15 -1027.67 2339.30 0.82 4750.43 24.06 333.45 4460.52 1306.10 -641.03 1454.50 0.55 Falls Creek #6 21 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (Incr) (ft) Dogleg Rate (o/100ft) 4812.89 23.75 332.58 4517.62 1328.65 -652.52 1479.79 0.75 4876.75 23.54 334.79 4576.12 1351.61 -663.87 1505.39 1.43 4938.56 23.12 333.80 4632.88 1373.66 -674.48 1529.86 0.93 7210.75 24.23 334.88 6701.16 2220.88 -1082.48 2470.07 1.22 7273.02 24.97 335.23 6757.77 2244.39 -1093.41 2495.99 1.21 7337.01 25.97 335.38 6815.54 2269.39 -1104.91 2523.51 1.56 7399.74 25.45 334.79 6872.07 2294.06 -1116.37 2550.72 0.92 7462.18 24.82 334.03 6928.59 2317.98 -1127.82 2577.24 1.13 7526.58 24.28 333.50 6987.17 2341.98 -1139.65 2603.98 0.91 7589.92 24.65 331.27 7044.82 2365.22 -1151.81 2630.18 1.57 7653.01 24.25 330.96 7102.26 2388.09 -1164.43 2656.23 0.67 7716.46 24.31 332.79 7160.09 2411.10 -1176.73 2682.27 1.19 7779.05 23.34 332.69 7217.35 2433.57 -1188.31 2707.53 1.55 7842.82 24.36 333.05 7275.67 2456.52 -1200.06 2733.29 1.61 7905.68 25.84 333.78 7332.60 2480.37 -1211.99 2759.94 2.41 7968.19 26.84 333.35 7388.62 2505.20 -1224.34 2787.66 1.63 8030.18 28.20 333.54 7443.59 2530.82 -1237.14 2816.29 2.20 8092.54 29.14 333.64 7498.31 2557.61 -1250.45 2846.19 1.52 8157.12 29.51 333.64 7554.61 2585.96 -1264.49 2877.81 0.58 8219.14 30.74 333.54 7608.25 2613.84 -1278.34 2908.93 1.98 8284.14 31.96 334.03 7663.76 2644.18 -1293.28 2942.74 1.91 8346.66 32.91 334.05 7716.52 2674.32 -1307.96 2976.26 1.51 8408.98 34.05 334.80 7768.51 2705.33 -1322.80 3010.63 1.95 8470.42 35.74 336.16 7818.90 2737.31 -1337.37 3045.77 3.02 8534.65 37.11 336.71 7870.58 2772.26 -1352.61 3083.89 2.19 8598.58 38.22 337.27 7921.19 2808.22 -1367.88 3122.94 1.83 8661.89 37.55 336.75 7971.15 2844.01 -1383.06 3161.80 1.17 8724.87 37.23 336.05 8021.19 2879.06 -1398.37 3200.04 0.85 8787.63 36.68 335.95 8071.34 2913.53 -1413.72 3237.77 0.87 8850.41 36.28 335.82 8121.82 2947.60 -1428.97 3275.09 0.66 8914.68 35.96 334.92 8173.74 2982.03 -1444.76 3312.97 0.96 8976.64 35.86 334.61 8223.93 3014.90 -1460.25 3349.31 0.34 9025.92 35.55 333.99 8263.94 3040.82 -1472.72 3378.06 0.96 9060.00 35.55 333.99 8291.67 3058.62 -1481.41 3397.87 0.01 Fa l l s C r e e k # 6 22 4. 2 B i t R e c o r d BI T NO . SI Z E TY P E S/ N JE T S / TF A IN OU T FT HR S AV E RO P Ft / H R CONDITION 1 1 2 . 2 5 ” HD B S F X 6 6 M PD C 12 0 3 8 2 6 7 9 x 1 2 0. 9 9 4 0 72 ’ 3 5 3 0 ’ 3 4 5 8 ’ 2 6 . 6 7 1 2 9 1 - 3 - B T - S - X - 1 B U - T D 2 8 . 5 ” HD B S M M 6 5 M PD C 12 5 5 0 2 3 2 6 x 1 2 0. 6 6 2 7 35 3 0 ’ 9 0 6 0 ’ 5 5 3 0 ’ 6 3 . 1 5 1 3 9 1 - 2 - P N - N - X - 1 C T - T D Fa l l s C r e e k # 6 23 4. 3 M u d R e c o r d Co n t r a c t o r : M . I . S w a c o De p t h Da t e MD ( f t ) TV D (f t ) MW (p p g ) VI S (s / q t ) PV YP Ge l s FL (c c ) FC So l s (% ) O/ W Ra t i o Sd (% ) MB T pH Cl (ml/l) Ca (ml/l) Sp u d M u d 10 / 1 8 / 2 0 1 4 0 0 8 . 6 4 1 1 0 16 8 / 1 4 / 1 6 1 5 2 / - 2 . 0 /9 8 - 1 2 . 0 9 . 6 4 0 0 2 0 10 / 1 9 / 2 0 1 4 5 6 1 5 6 1 9 . 0 2 2 0 5 1 5 0 29 / 5 3 / 7 4 1 3 . 8 2 / - 3 . 0 / 97 0 . 2 5 2 4 . 0 9 . 7 3 0 0 8 0 10 / 2 0 / 2 0 1 4 2 0 3 9 1 9 9 0 8 . 9 1 6 0 5 0 5 0 28 / 5 3 / 7 3 6 . 2 2 / - 4 . 0 / 96 1 . 0 0 1 4 . 0 9 . 3 2 0 0 8 0 10 / 2 1 / 2 0 1 4 3 3 2 3 3 1 5 6 9 . 0 1 6 3 4 5 4 7 27 / 3 8 / 4 1 7 . 8 2 / - 3 . 0 / 97 1 . 0 0 1 6 . 0 9 . 4 2 0 0 8 0 10 / 2 2 / 2 0 1 4 3 5 3 0 3 3 4 6 9 . 2 1 6 5 5 0 5 0 27 / 3 7 / 4 3 5 . 6 2 / - 3 . 0 / 97 1 . 0 0 1 6 . 0 8 . 2 3 0 0 8 0 10 / 2 3 / 2 0 1 4 3 5 3 0 3 3 4 6 9 . 1 5 8 2 3 2 7 8/ 1 2 / 1 4 5 . 6 2 / - 3 . 0 / 97 0 . 7 5 1 6 . 0 8 . 0 2 0 0 8 0 10 / 2 4 / 2 0 1 4 3 5 3 0 3 3 4 6 9 . 1 8 2 1 0 2 0 6/ 8 / 1 0 5 . 0 2 / - 3 . 0 / 97 0 . 2 5 1 8 . 0 9 . 5 3 3 0 0 0 7 0 10 / 2 5 / 2 0 1 4 3 5 3 0 3 3 4 6 9 . 1 5 6 1 0 2 1 6/ 9 / 1 1 5 . 0 2 / - 4 . 0 / 96 0 . 0 0 2 . 0 9 . 6 3 2 0 0 0 8 0 10 / 2 6 / 2 0 1 4 3 5 3 0 3 3 4 6 9 . 1 5 6 1 0 2 1 6/ 9 / 1 1 5 . 0 2 / - 4 . 0 / 96 0 . 0 0 3 . 0 9 . 6 3 2 0 0 0 8 0 10 / 2 7 / 2 0 1 4 3 5 3 0 3 3 4 6 9 . 1 5 7 1 1 2 0 6/ 9 / 1 2 4 . 0 1 / - 3 . 0 / 96 0 . 0 0 3 . 0 9 . 5 3 3 0 0 0 8 0 10 / 2 8 / 2 0 1 4 3 5 3 0 3 3 4 6 9 . 1 5 7 1 7 2 0 7/ 9 / 1 1 5 . 0 1 / 1 4 . 0 / 96 0 . 0 0 3 . 0 9 . 5 3 3 0 0 0 8 0 10 / 2 9 / 2 0 1 4 3 5 3 0 3 3 4 6 9 . 1 5 5 1 0 2 0 5/ 8 / 1 0 5 . 0 1 / 1 4 . 0 /9 6 0 . 0 0 3 0 9 . 4 3 2 0 0 0 8 Kl a - S h i e l d 10 / 3 0 / 2 0 1 4 3 5 6 6 3 3 7 8 9 . 0 4 3 1 0 1 6 4/ 6 / 8 6 . 0 1 / 1 4 0 / 96 0 . 0 0 3 . 0 9 . 5 2 9 0 0 0 3 6 0 10 / 3 1 / 2 0 1 4 5 0 3 5 4 7 2 3 9 . 2 5 6 1 2 2 3 8/ 1 2 / 1 5 5 . 4 1 / 1 3 . 2 / 94 0 . 1 0 3 . 2 9 . 7 3 4 0 0 0 4 8 0 11 / 0 1 / 2 0 1 4 6 0 8 4 5 6 7 7 9 . 2 5 9 1 3 2 7 8/ 1 1 / 1 4 4 . 6 1 / 1 7 . 0 / 93 0 . 1 0 3 . 4 9 . 6 3 3 0 0 0 4 0 0 11 / 0 2 / 2 0 1 4 7 2 7 5 6 7 5 9 9 . 3 5 2 1 4 2 3 7/ 1 0 / 1 2 4 . 7 1 / 1 7. 0 . 2 / 9 1 0 . 1 5 3. 8 9 . 4 3 3 0 0 0 3 6 0 11 / 0 3 / 2 0 1 4 8 0 1 5 7 5 0 9 9 . 2 5 3 1 5 2 2 6/ 8 / 1 0 4 . 7 1 / 2 7 . 0 3 / 91 0 . 1 0 4 . 2 9 . 5 3 4 0 0 0 3 6 0 11 / 0 4 / 2 0 1 4 8 4 8 4 7 8 3 1 9 . 3 5 4 1 5 2 4 6/ 8 / 1 0 4 . 4 1 / 1 7 . 0 3 / 90 0 . 1 0 4 . 6 9 . 3 3 6 0 0 0 3 2 0 11 / 0 5 / 2 0 1 4 8 8 1 1 8 0 8 8 9 . 4 5 2 1 8 1 9 6/ 8 / 1 0 4 . 3 1 / 1 7 . 0 3 / 90 0 . 1 0 4 . 8 9 . 6 3 8 0 0 0 2 8 0 11 / 0 6 / 2 0 1 4 9 0 6 0 8 2 9 2 9 . 3 6 0 1 7 2 4 6/ 7 / 9 4 . 3 1 / 2 7 . 0 3 / 90 0 . 2 0 5 . 0 9 . 3 3 5 0 0 0 2 8 0 11 / 0 7 / 2 0 1 4 9 0 6 0 8 2 9 2 9 . 3 6 0 1 5 2 1 6/ 7 / 9 4 . 3 1 / 2 7 . 0 3 / 90 0 . 1 0 5 . 0 9 . 4 3 5 0 0 0 2 8 0 11 / 0 8 / 2 0 1 4 9 0 9 0 8 2 9 2 9 . 4 7 0 1 6 2 3 6/ 7 / 9 4 . 3 1 / 2 6 . 5 3 / 91 0 . 1 0 5 . 0 9 . 4 3 5 0 0 0 2 0 0 Ab b r e v i a t i o n s : MW = M u d W e i g h t V I S = F u n n e l V i s c o s i t y PV = P l a s t i c V i s c o s i t y Y P = Y i e l d P o i n t G e l s = G e l S t r e n g t h F L = W a t e r o r F i l t r a t e Lo s s F C = F i l t e r C a k e O / W = O i l t o W a t e r r a t i o S o l s = S o l i d s S d = S a n d c o n t e n t M B T = M e t h y l e n e B l u e A l k , P m = A l k a l i n i t y , M u d pH = A c i d i t y C l = C h l o r i d e s C a = H a r d n e s s C a l c i u m n r = N o t R e c o r d e d Fa l l s C r e e k # 6 24 4. 4 D r i l l i n g P r o g r e s s C h a r t 0 50 0 10 0 0 15 0 0 20 0 0 25 0 0 30 0 0 35 0 0 40 0 0 45 0 0 50 0 0 55 0 0 60 0 0 65 0 0 70 0 0 75 0 0 80 0 0 85 0 0 90 0 0 95 0 0 10 0 0 0 1 0 / 1 7 / 1 4 1 0 / 1 8 / 1 4 1 0 / 1 9 / 1 4 1 0 / 2 0 / 1 4 1 0 / 2 1 / 1 4 1 0 / 2 2 / 1 4 1 0 / 2 3 / 1 4 1 0 / 2 4 / 1 4 1 0 / 2 5 / 1 4 1 0 / 2 6 / 1 4 1 0 / 2 7 / 1 4 1 0 / 2 8 / 1 4 1 0 / 2 9 / 1 4 1 0 / 3 0 / 1 4 1 0 / 3 1 / 1 4 1 1 / 1 / 1 4 1 1 / 2 / 1 4 1 1 / 3 / 1 4 1 1 / 4 / 1 4 1 1 / 5 / 1 4 1 1 / 6 / 1 4 1 1 / 7 / 1 4 1 1 / 8 / 1 4 1 1 / 9 / 1 4 1 1 / 1 0 / 1 4 1 1 /1 1 /1 4 D E P T H (F T ) 12 1/4" Hole 8 1/2" Hole Falls Creek #6 25 5 SHOW REPORTS Hydrocarbon Show Report # 1 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 5050 MD 5126 MD Country: 4735 TVD 4804 TVD Averages Before During After Maximum ROP (fph) 157 151 186 296 WOB 10.2 9.8 10.7 15.0 RPM 45 38 61 70 Mud Weight 9.2 9.2 9.2 9.2 Chloride 33,000 33,000 33,000 33,000 Total Gas 140 335 181 908 C1 (ppm) 26,592 58,588 15,408 171,016 C2 (ppm) 1 77 - 315 C3 (ppm) - 9 - 45 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/SANSTONE = Dark medium gray color; quartz clasts translucent to dirty grayish white to black color; poorly sorted from very fine to upper coarse grains; angular to subrounded grains with low to fair sphericity; young textural maturity; loose unconsolidated sands are composed quartz and sand sized clasts of tuffaceous siltstone, black carbonaceous materials, trace calcite and biotite and interbedded with sandstone; the sandstone is heavily indurated with a tight visual porosity; grain supported and a matrix cement none reactive to Hydrochloric Acid; individual quartz grains fine to lower medium grain size; interbedded through is thinly structured shards of coal with visible degassing; indicating a loose chambered structure. Hilcorp Alaska, LLC. 133-20645-00-00 Falls Creek #6 Cook Inlet Basin Saxon 147 1-Nov-14 1:27 Kenai Peninsula Borough Alaska United States of America Tyler Harris Gas show Pixler Plot 1 10 100 1000 10000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 2 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 7372 MD 7437 MD Country: 6847.07 TVD 6905.8 TVD Averages Before During After Maximum ROP (fph) 113 188 180 349 WOB 15.0 13.0 14.0 16.0 RPM 60 57 63 60 Mud Weight 9.2 9.2 9.2 9.2 Chloride 33,000 33,000 33,000 33,000 Total Gas 42 404 77 925 C1 (ppm) 8,133 77,528 15,061 177,592 C2 (ppm) 32 292 31 677 C3 (ppm) - 13 - 44 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: TUFFACEOUS SANDSTONE ( 7385' - 7450' ) = Dirty grayish white overall color; matrix supported; with upper fine to lower medium grain size; well sorted with fair to moderate sphericity; textural maturity is well aged; matrix is composed of volcanic ash and tuff and devitrified glass is in evidence; clasts of coal are entrained with sandstone; coals are visibly degassing; larger clasts of coal are signs of popping of the walls from above. Hilcorp Alaska, LLC. 133-20645-00-00 Falls Creek #6 Cook Inlet Basin Saxon 147 3-Nov-14 2:21 Kenai Peninsula Borough Alaska United States of America HARRY E. BLEYS Gas show. This is a gas well so no oil indicator, but with the gases present it will be a very productive gas well. The pixler plot shows we are in gas. Pixler Plot 1 10 100 1000 10000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OIL NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Falls Creek #6 26 6 DAILY REPORTS Hillcorp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT Falls Creek #6 REPORT FOR J. Lott / S. BARBER DATE Nov 09, 2014 DEPTH 9060 PRESENT OPERATION Preparing to run casing. TIME 23:59:59 YESTERDAY 9060 24 HOUR FOOTAGE 0 CASING INFORMATION 16"@72' 9.625"@3530' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9060 35.55 333.99 8291.67 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 5035' MW 9.3 VIS 60 PV 17 YP 24 FL 4.3 Gels 6/7/9 CL- 35000 FC 1/2 SOL 7 SD 0.2 OIL .3/90 MBT 5 pH 9.3 Ca+ 280 Alk MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY TUFFACEOUS SANDSTONE 90%, AND TUFF 10%. DAILY ACTIVITY SUMMARY Circulate bottoms up and pump a slug prior to dropping wiper tool. Pull out of hole laying down drill pipe. Remove bit and bit sub. Drain blow out preventers and rigup bushing puller and pull wear bushing. Pick up and run casing hanger. Change out upper rams to 5.5 inch. Rig up test equipment and pressure test upper rams to 250 low psi and 3500 high psi for five minutes. Rig down test equipment. Rid down elevators and elevator links. Clean rig floor and prep for casing run. Preparing to have a pre job safety meeting with casing crew. CANRIG PERSONNEL ON BOARD 2 DAILY COST $2148.00 REPORT BY HARRY E. BLEYS Hillcorp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT Falls Creek #6 REPORT FOR J. Lott / S. BARBER DATE Nov 08, 2014 DEPTH 9060 PRESENT OPERATION Drilling ahead. TIME 23:59:59 YESTERDAY 9060 24 HOUR FOOTAGE 0 CASING INFORMATION 16"@72' 9.625"@3530' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9060 35.55 333.99 8291.67 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 5035' MW 9.3 VIS 60 PV 17 YP 24 FL 4.3 Gels 6/7/9 CL- 35000 FC 1/2 SOL 7 SD 0.2 OIL .3/90 MBT 5 pH 9.3 Ca+ 280 Alk MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 0 CUTTING GAS @ @ WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) @ @ CONNECTION GAS HIGH 0 ETHANE (C-2) @ @ AVG 0 PROPANE (C-3) @ @ CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 0 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY TUFFACEOUS SANDSTONE 90%, AND TUFF 10%. DAILY ACTIVITY SUMMARY HELD SAFETY MEETING AND PREPARED TO RIG UP WIRELINE CREW. RIGGED UP AND RAN IN HOLE. LATCH SURVEY TOOL INTO BIT SUB. RELEASE FROM TOOL AND WIRELINE PULL OUT OF HOLE. HOLD SAFETY MEETING WITH WIRELINE CREW AND RIGGED DOWN WIRELINE EQLUIPMENT. PULLED OUT OF HOLE WITH MEMORY LOGS. RIGGED UP SLB E-LINE TO ATTEMPT TO RETRIEVE LOGGING TOOLS. NO SUCCESS SO RIGGED DOWN E-LINE. COMMENCE LAYING DOWN DRILL PIPE AS PULLING OUT OF HOLE. STARTING FROM 3201 FT. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3077.00 REPORT BY HARRY E. BLEYS Hillcorp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT Falls Creek #6 REPORT FOR J. Lott / S. Barber DATE Nov 7, 2014 DEPTH 9160.00000 PRESENT OPERATION Tripping in hole to log to bottom. TIME 23:59:59 YESTERDAY 8797.00000 24 HOUR FOOTAGE 363 CASING INFORMATION 16"@72' 9.625"@ 3498' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9060 35.55 333.99 8291.67 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" HDBS PDC MM65M 12550232 6X12 3530' 9060' 4225' 63.15 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 125.0 @ 8958.00000 6.1 @ 8951.00000 42.4 FT/HR SURFACE TORQUE 20376 @ 9012.00000 17913 @ 8803.00000 13914.8 AMPS WEIGHT ON BIT 10 @ 8939.00000 2 @ 8951.00000 4.8 KLBS ROTARY RPM 71 @ 8895.00000 44 @ 8887.00000 44.6 RPM PUMP PRESSURE 2885 @ 8964.00000 2616 @ 8887.00000 1981.7 PSI DRILLING MUD REPORT DEPTH 9060 MW 9.3 VIS 60 PV 17 YP 24 FL 4.3 Gels 6/7/9 CL- 35000 FC 1/2 SOL 7 SD 0.2 OIL 3/90 MBT 5 pH 9.3 Ca+ 280 Alk MWD SUMMARY INTERVAL 8797' TO 9060' TOOLS MUD MOTOR AND DIRECTIONAL MODULE GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 599 @ 8987.00000 17 @ 8813.00000 51.1 TRIP GAS 0 CUTTING GAS 0 @ 9160.00000 0 @ 9160.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 162065 @ 8987.00000 3492 @ 8813.00000 13253.0 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 9160.00000 0 @ 9160.00000 0.0 AVG 0 PROPANE (C-3) 0 @ 9160.00000 0 @ 9160.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 9160.00000 0 @ 9160.00000 0.0 CURRENT BACKGROUND/AVG 2/51 PENTANE (C-5) 0 @ 9160.00000 0 @ 9160.00000 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TYONEK PRESENT LITHOLOGY TUFFACEOUS SANDSTONE 90%, TUFF 10% DAILY ACTIVITY SUMMARY DRILLED UNTIL 9060 Ft. AND T.D. WELL. CIRCULATED BOTTOMS UP AND PUMPED SWEEP AND BEGAN TRIPPING OUT OF HOLE. REACHED SURFACE AND BEGAN LAYING DOWN TOOLS. BROKE OPEN MWD TOOLS AND DOWNLOADED ALL DATA. RIGGED DOWN AND RIGGED UP TO WIRELINE WELL. TRIPPED IN HOLE AND AT PRESENT AT 6879 Ft. LOGGING WELL. MAX GAS 599 u AT 8987 Ft. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3077.00 REPORT BY HARRY E. BLEYS Hillcorp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT Falls Creek #6 REPORT FOR J. Lott/ S. Barber DATE Nov 06, 2014 DEPTH 8797.00000 PRESENT OPERATION Drilling ahead. TIME 23:59:59 YESTERDAY 8484.00000 24 HOUR FOOTAGE 313 CASING INFORMATION 16"@72' 9.625"@ 3498' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8787.63 36.68 335.95 8071.34 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5 HDBS PDC MM65M 12550232 6X12 3530' 38636 59.65 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 252.7 @ 8504.00000 1.2 @ 8487.00000 72.6 97.72492 FT/HR SURFACE TORQUE 19714 @ 8779.00000 1334 @ 8508.00000 14308.3 18618.75977 AMPS WEIGHT ON BIT 19 @ 8487.00000 0 @ 8600.00000 7.1 8.41000 KLBS ROTARY RPM 79 @ 8616.00000 3 @ 8576.00000 48.8 57.50000 RPM PUMP PRESSURE 2887 @ 8501.00000 2392 @ 8484.00000 2673.7 2814.17993 PSI DRILLING MUD REPORT DEPTH 8811' MW 9.4 VIS 52 PV 18 YP 19 FL 96.4 Gels 6/8/10 CL- 38000 FC 1/1 SOL 7 SD 0.1 OIL 3/90 MBT 4.8 pH 9.6 Ca+ 280 Alk MWD SUMMARY INTERVAL 8484' TO 8797' TOOLS MUD MOTOR, AND DIRECTIONAL MODULE. GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 544 @ 8652.00000 6 @ 8484.00000 49.3 TRIP GAS 454 CUTTING GAS 0 @ 8797.00000 0 @ 8797.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 168610 @ 8652.00000 1736 @ 8484.00000 14048.0 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 8797.00000 0 @ 8797.00000 0.0 AVG 0 PROPANE (C-3) 0 @ 8797.00000 0 @ 8797.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 8797.00000 0 @ 8797.00000 0.0 CURRENT BACKGROUND/AVG 30/49 PENTANE (C-5) 0 @ 8797.00000 0 @ 8797.00000 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY TUFFACEOUS SANDSTONE 40%, SAND 30%,AND TUFFACEOUS SILTSTONE 30%. DAILY ACTIVITY SUMMARY TRIPPED OUT OF HOLE TO SOLVE AND WORK ON MUD PUMPS. TRIPPED BACK IN AND RECIEVED 454 u OF TRIP GAS. COMMENCED DRILLING AND STILL DRILLLING AT REPORT TIME. MAX GAS 544 u. AT 8652 Ft. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3077.00 REPORT BY HARRY E. BLEYS Hillcorp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT Falls Creek #6 REPORT FOR J. Lott / S. Barber DATE Nov 05, 2014 DEPTH 8484.00000 PRESENT OPERATION Tripping out of hole. TIME 23:59:59 YESTERDAY 8105.00000 24 HOUR FOOTAGE 379 CASING INFORMATION 16"@72' 9.625"@3498' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8408.98 34.05 334.8 7768.51 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" HDBS PDC MM65M 12550232 6X12 3530' 3459' 50.83 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 283.0 @ 8416.00000 1.3 @ 8467.00000 75.1 18.57844 FT/HR SURFACE TORQUE 19387 @ 8282.00000 1318 @ 8382.00000 9258.9 1747.17004 AMPS WEIGHT ON BIT 16 @ 8282.00000 0 @ 8470.00000 5.5 0.00000 KLBS ROTARY RPM 71 @ 8157.00000 1 @ 8271.00000 31.2 0.00000 RPM PUMP PRESSURE 2729 @ 8439.00000 1856 @ 8105.00000 2326.9 2392.03003 PSI DRILLING MUD REPORT DEPTH 8484' MW 9.3 VIS 54 PV 15 YP 24 FL 9.4 Gels 6/8/10 CL- 36000 FC 1/1 SOL 7 SD 0.1 OIL 3/91 MBT 4.6 pH 9.3 Ca+ 320 Alk MWD SUMMARY INTERVAL 8105' TO 8484' TOOLS MUD MOTOR, AND DIRECTIONAL MODULE GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 991 @ 8413.00000 5 @ 8483.00000 144.8 TRIP GAS CUTTING GAS 0 @ 8484.00000 0 @ 8484.00000 0.0 WIPER GAS 657 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 207046 @ 8405.00000 1104 @ 8483.00000 28967.3 CONNECTION GAS HIGH 0 ETHANE (C-2) 883 @ 8160.00000 0 @ 8442.00000 175.3 AVG 0 PROPANE (C-3) 59 @ 8405.00000 0 @ 8442.00000 3.7 CURRENT 0 BUTANE (C-4) 0 @ 8484.00000 0 @ 8484.00000 0.0 CURRENT BACKGROUND/AVG 0/145 PENTANE (C-5) 0 @ 8484.00000 0 @ 8484.00000 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY TUFFACEOUS SANDSTONE 70%, TUFFACEOUS SILTSTONE 20%, AND SAND 10%. DAILY ACTIVITY SUMMARY PUMPED TWO CONSECUTIVE SWEEPS AND GOT 75% RETURNS AND 50% RETURNS. HELD A PRE JOB SAFETY MEETING AND CHECKED FLOW IN THE WELL. COMMENCED PULLING OUT OF HOLE FROM 8484 Ft. WIPER GAS OF 657 u.AT 8104 Ft. AND MAX GAS OF 991 AT 8413 Ft. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3077.00 REPORT BY HARRY E. BLEYS Hillcorp Alaska, LLC Kenai Inlet Basin DAILY WELLSITE REPORT Falls Creek #6 REPORT FOR D. Yessack / J. Lott DATE Nov 04, 2014 DEPTH 8105.00000 PRESENT OPERATION Performing short trip out of hole while checking for a washed out pipe. TIME 23:59:59 YESTERDAY 7260.00000 24 HOUR FOOTAGE 845 CASING INFORMATION 16"@72' 9.625"@ 3498' 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 2 8.5" HDBS PDC MM65M 12550232 6x12 3530' 3080 43.16 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 948.4 @ 7758.00000 1.8 @ 7562.00000 113.9 25.82249 FT/HR SURFACE TORQUE 18313 @ 8053.00000 1314 @ 8004.00000 12877.8 16857.95000 AMPS WEIGHT ON BIT 16 @ 7383.00000 0 @ 7893.00000 7.1 8.89000 KLBS ROTARY RPM 67 @ 7484.00000 6 @ 7689.00000 43.7 50.51000 RPM PUMP PRESSURE 2470 @ 7767.00000 1005 @ 8068.00000 2252.0 1856.44000 PSI DRILLING MUD REPORT DEPTH 7275' MW 9.3 VIS 52 PV 14 YP 23 FL 4.7 Gels 7/10/12 CL- 33000 FC 1/1 SOL 7 SD OIL /92 MBT 3.8 pH 9.4 Ca+ 380 Alk MWD SUMMARY INTERVAL 7260' TO 8108' TOOLS Mud Motor and Directional Module GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 925 @ 7402.00000 11 @ 8005.00000 121.2 TRIP GAS CUTTING GAS 0 @ 8105.00000 0 @ 8105.00000 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 177592 @ 7402.00000 121 @ 7689.00000 23073.3 CONNECTION GAS HIGH ETHANE (C-2) 677 @ 7402.00000 0 @ 7689.00000 85.2 AVG PROPANE (C-3) 50 @ 7813.00000 0 @ 7753.00000 1.2 CURRENT BUTANE (C-4) 0 @ 8105.00000 0 @ 8105.00000 0.0 CURRENT BACKGROUND/AVG PENTANE (C-5) 0 @ 8105.00000 0 @ 8105.00000 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY TUFFACEOUS SILTSTONE 90%, AND TUFFACEOUS SANDSTONE 10% DAILY ACTIVITY SUMMARY Drilled all day and started to lose stand pipe pressure. Continued lose over several hours of 400 psi in possible washout in drill pipe. Circulated a sweep out and flow checked well. Continued to check for washed out drill pipe while tripping out of hole. Max gas 925 u at 7402'. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3077.00 REPORT BY HARRY E. BLEYS Hillcorp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT Falls Creek #6 REPORT FOR D. Yessack/ J. Lott DATE Nov 03, 2014 DEPTH 7260.00000 PRESENT OPERATION Drilling ahead. TIME 23:53:24 YESTERDAY 6109.00000 24 HOUR FOOTAGE 1151 CASING INFORMATION 16'' @ 72' 9.625"@3498' 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 2 8.5" HDBS PDC MM65M 12550232 6X12 3530' 2235 34.00 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 703.6 @ 6317.00000 1.0 @ 7190.00000 154.1 33.33580 FT/HR SURFACE TORQUE 16883 @ 7249.00000 1293 @ 6930.00000 12434.4 1408.23999 AMPS WEIGHT ON BIT 14 @ 6140.00000 0 @ 6812.00000 9.4 8.06000 KLBS ROTARY RPM 82 @ 6712.00000 0 @ 6180.00000 51.8 0.00000 RPM PUMP PRESSURE 2435 @ 7154.00000 1457 @ 7180.00000 2228.3 2061.88989 PSI DRILLING MUD REPORT DEPTH 7275' MW 9.3 VIS 52 PV 14 YP 23 FL 9.8 Gels 7/10/12 CL- 33000 FC 1/1 SOL 7 SD 0.15 OIL 2/91 MBT 3.8 pH 9.4 Ca+ 360 Alk MWD SUMMARY INTERVAL 6109' TO 7260' TOOLS MUD MOTOR AND DIRECTIONAL MODULE GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 725 @ 6825.00000 3 @ 6640.00000 146.9 TRIP GAS 276 CUTTING GAS 0 @ 7260.00000 0 @ 7260.00000 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 129563 @ 6825.00000 623 @ 6640.00000 24540.8 CONNECTION GAS HIGH ETHANE (C-2) 570 @ 7240.00000 0 @ 6178.00000 67.5 AVG PROPANE (C-3) 64 @ 6826.00000 0 @ 6178.00000 2.9 CURRENT BUTANE (C-4) 0 @ 7260.00000 0 @ 7260.00000 0.0 CURRENT BACKGROUND/AVG 146/396 PENTANE (C-5) 0 @ 7260.00000 0 @ 7260.00000 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY TUFFACEOUS SANDSTONE 60%, TUFFACEOUS SILTSTONE 20%, TUFFACEOUS CLAYSTONE 10%, AND TUFF 10%. DAILY ACTIVITY SUMMARY Drilled ahead all day and stopped and circulated and pumped a sweep than pulled a short trip 7117 Ft to the shoe. Tripped back to bottom and had 276u of trip gas. Max gas was 725 u at 6825 Ft. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3077.00 REPORT BY HARRY E. BLEYS Hillcorp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT Falls Creek #6 REPORT FOR D. Yessak/J. Lott DATE Nov 02, 2014 DEPTH 6109' PRESENT OPERATION Drilling ahead TIME 23:59:59 YESTERDAY 5035' 24 HOUR FOOTAGE 1074' CASING INFORMATION 16" @ 72' 9.625 @ 3498' 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 2 8.5" HDBS PDC MM65M 12550232 6x12 3530 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 4491.4 @ 5793 1.1 @ 5452 172.5 169.3 FT/HR SURFACE TORQUE 15927 @ 5664 1340 @ 5857 11023.4 12797.3 AMPS WEIGHT ON BIT 23 @ 5793 0 @ 5544 9.8 8.0 KLBS ROTARY RPM 84 @ 5904 0 @ 5050 54.4 65.1 RPM PUMP PRESSURE 2272 @ 5971 648 @ 5163 1865.0 2140.7 PSI DRILLING MUD REPORT DEPTH MW 9.2 VIS 59 PV 13 YP 27 FL 4.6 Gels 8/11/14 CL- 33000 FC 1/1 SOL 7 SD 0.1 OIL /93 MBT 3.4 pH 9.6 Ca+ 400 Alk 1.1 MWD SUMMARY INTERVAL 5035' TO 6109' TOOLS MUD MOTOR, GAMMA, RESISTIVITY, AND DIRECTIONAL MODULE GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 908 @ 5076 -1 @ 5832 227.0 TRIP GAS 380 CUTTING GAS 0 @ 6109 0 @ 6109 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 1675931 @ 5592 0 @ 5832 68213.7 CONNECTION GAS HIGH 0 ETHANE (C-2) 2719 @ 5592 0 @ 5832 72.1 AVG 0 PROPANE (C-3) 672 @ 5592 0 @ 5832 17.6 CURRENT 0 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 32/227 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY TYONEK FORMATION PRESENT LITHOLOGY TUFFACEOUS SANDSTONE 90%, SAND 10% DAILY ACTIVITY SUMMARY DRILLED ALL DAY UNTIL 6109Ft. AND PERFORMED SHORT TRIP TO SHOE. CIRCULATED PRIOR TO SHORT TRIP AND PUMPED A SWEEP AROUND. TRIPPED BACK IN HOLE AND REACHED BOTTOM WITH 380 u. OF TRIP GAS. MAX GAS WAS 908u @ 5070 Ft. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3077.00 REPORT BY HARRY E. BLEYS Hillcorp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT Falls Creek #6 REPORT FOR D. Yessack / J. Lott DATE Nov 01, 2014 DEPTH 3622.00000 PRESENT OPERATION Drilling ahead. TIME 23:59:59 YESTERDAY 5035.00000 24 HOUR FOOTAGE -1413 CASING INFORMATION 16"@72' 9.625"@3530' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 5001.17 23.30 335.43 4690.42 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" HDBS PDC MM65M 12550232 6X12 3530' 1506' 14.51 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 867 @ 4548 1.9 @ 4911 167.6 208.62589 FT/HR SURFACE TORQUE 13385 @ 4949 1328 @ 3916 9825.9 12497.24023 AMPS WEIGHT ON BIT 15 @ 4181 0 @ 4714 8.0 11.86 KLBS ROTARY RPM 84 @ 4092 34 @ 3643 57.9 59.8 RPM PUMP PRESSURE 1837 @ 4752 1140 @ 3778 1609.9 1777.17004 PSI DRILLING MUD REPORT DEPTH 5035' MW 9.2 VIS 56 PV 12 YP 23 FL 5.4 Gels 8/12/15 CL- 34000 FC 1/1 SOL 6 SD 0.1 OIL /96 MBT 3.2 pH 9.7 Ca+ 480 Alk MWD SUMMARY INTERVAL 3622' TO 5035' TOOLS MUD MOTOR, AND DIRECTIONAL MODULE GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 654 @ 4779 9 @ 4436 119.2 TRIP GAS 50 CUTTING GAS 0 @ 5035 0 @ 5035 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 127284 @ 4779 1653 @ 4436 21127.7 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 0 0 @ 0 0 AVG 0 PROPANE (C-3) 0 @ 0 0 @ 0 0 CURRENT 0 BUTANE (C-4) 0 @ 0 0 @ 0 0 CURRENT BACKGROUND/AVG 444/119 PENTANE (C-5) 0 @ 0 0 @ 0 0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY TUFFACEOUS CLAYSTONE 70%, TUFFACEOUS SILTSTONE 20%, AND SAND 10% DAILY ACTIVITY SUMMARY DRILLED AHEAD ALL DAY UNTIL 5035' AND STOPPED CIRCULATED BOTTOMS UP PUMPED A SWEEP ALL AROUND AND COMMMENCED A SHORT TRIP TO THE SHOE. MAX GAS WAS 654 u. @ 4779 Ft. TRIP GAS WAS 50u AT 5035 FT. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3077.00 REPORT BY HARRY E. BLEYS Hillcorp Alaska, LLC Ninilchik DAILY WELLSITE REPORT Falls Creek #6 REPORT FOR D. Yessack/J. Lott DATE Nov 01, 2014 DEPTH 5035.00000 PRESENT OPERATION Drilling ahed. TIME 23:59:59 YESTERDAY 3622.00000 24 HOUR FOOTAGE 1413 CASING INFORMATION 16"@72' 9.625"@3530' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 5001.17 23.30 335.43 4690.42 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" HDBS PDC MM65M 12550232 6X12 3530' 1505' 14.51 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 867.0 @ 4548.00000 1.9 @ 4911.00000 167.6 208.62589 FT/HR SURFACE TORQUE 13385 @ 4949.00000 1328 @ 3916.00000 9825.9 12497.24023 AMPS WEIGHT ON BIT 15 @ 4181.00000 0 @ 4714.00000 8.0 11.86000 KLBS ROTARY RPM 84 @ 4092.00000 34 @ 3643.00000 57.9 59.80000 RPM PUMP PRESSURE 1837 @ 4752.00000 1140 @ 3778.00000 1609.9 1777.17004 PSI DRILLING MUD REPORT DEPTH 5035' MW 9.2 VIS 56 PV 12 YP 23 FL 5.4 Gels 8/12/15 CL- 34000 FC 1/1 SOL 6 SD 0.1 OIL /96 MBT 3.2 pH 9.7 Ca+ 480 Alk MWD SUMMARY INTERVAL 3622' TO 5035' TOOLS MUD MOTOR AND DIRECTIONAL MODULES GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 654 @ 4779.00000 9 @ 4436.00000 119.2 TRIP GAS 50 CUTTING GAS 0 @ 5035.00000 0 @ 5035.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 127284 @ 4779.00000 1653 @ 4436.00000 21127.7 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 5035.00000 0 @ 5035.00000 0.0 AVG 0 PROPANE (C-3) 0 @ 5035.00000 0 @ 5035.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 5035.00000 0 @ 5035.00000 0.0 CURRENT BACKGROUND/AVG 444/119 PENTANE (C-5) 0 @ 5035.00000 0 @ 5035.00000 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY TUFFACEOUS CLAYSTONE 70%, TUFFACEOUS SILTSTONE 20%, AND SAND 10% DAILY ACTIVITY SUMMARY Drilled ahead all day until 5035 Ft. and stopped circulated bottoms up. Pumped a sweeps all around and commenced a short to to the shoe. Max gas was 654 u. @ 4779 Ft. Trip gas 50 u at 5035 Ft. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3077.00 REPORT BY Harry E. Bleys Hillcorp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT Falls Creek #6 REPORT FOR D. Yessack/J. Lott DATE Oct 31, 2014 DEPTH 3622.00000 PRESENT OPERATION Drilling ahead. TIME 23;59;59 YESTERDAY 3530.00000 24 HOUR FOOTAGE 92 CASING INFORMATION 16"@72' 9.625"@3530' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 3616.88 24.83 333.93 3424.07 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED 2 8.5" HDBS PDC MM65M 12550232 6X12 3530' 92 5.5 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 254.0 @ 3542.00000 17.7 @ 3534.00000 135.6 126.47929 FT/HR SURFACE TORQUE 9940 @ 3530.00000 1423 @ 3551.00000 7539.2 8619.30957 AMPS WEIGHT ON BIT 14 @ 3530.00000 0 @ 3596.00000 4.2 2.73000 KLBS ROTARY RPM 73 @ 3530.00000 1 @ 3541.00000 17.9 36.79000 RPM PUMP PRESSURE 1949 @ 3530.00000 814 @ 3532.00000 1342.6 1374.83997 PSI DRILLING MUD REPORT DEPTH 3566' MW 9.0 VIS 43 PV 10 YP 16 FL 6 Gels 4/6/8 CL- 29000 FC 1/- SOL 6 SD OIL /96 MBT 3 pH 9.5 Ca+ 360 Alk MWD SUMMARY INTERVAL 3530' TO 3622 TOOLS MUD MOTOR AND DIRECTIONAL MODULE GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 452 @ 3622.00000 2 @ 3551.00000 83.6 TRIP GAS 0 CUTTING GAS 0 @ 3622.00000 0 @ 3622.00000 0.0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 79272 @ 3621.00000 420 @ 3551.00000 15215.4 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 3622.00000 0 @ 3622.00000 0.0 AVG 0 PROPANE (C-3) 0 @ 3622.00000 0 @ 3622.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 3622.00000 0 @ 3622.00000 0.0 CURRENT BACKGROUND/AVG 46/84 PENTANE (C-5) 0 @ 3622.00000 0 @ 3622.00000 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY SAND 60%, TUFFACEOUS CLAYSTONE 10%, TUFFACEOUS SILTSTONE 30%. DAILY ACTIVITY SUMMARY Pulled out of hole and put on new tools for drilling. Tripped back in hole and drilled out cement and 20 ft of rathole. Performed FIT test to 12.0 ppg. Commenced drilling and still drilling at report time. Max gas 452u @ 3622 Ft. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3077.00 REPORT BY HARRY E. BLEYS Hillcorp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT Falls Creek #6 REPORT FOR Doug Yessack/James Lott DATE Oct 29, 5019 DEPTH 3530 PRESENT OPERATION TRIPPING IN HOLE. TIME 23:59:59 YESTERDAY 3530 24 HOUR FOOTAGE 0 CASING INFORMATION 16" @ 72' 9.625" @ 3530' 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 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 0.0 @ 3530.00000 0 @ 3530.00000 0.0 59.57127 FT/HR SURFACE TORQUE 0 @ 3530.00000 0 @ 3530.00000 0.0 9940.33984 AMPS WEIGHT ON BIT 0 @ 3530.00000 0 @ 3530.00000 0.0 14.43000 KLBS ROTARY RPM 0 @ 3530.00000 0 @ 3530.00000 0.0 73.44000 RPM PUMP PRESSURE 0 @ 3530.00000 0 @ 3530.00000 0.0 1949.26001 PSI DRILLING MUD REPORT DEPTH 3530' MW 9.1 VIS 57 PV 11 YP 20 FL 5 Gels 7/9/11 CL- 33000 FC 1/- SOL 4 SD OIL /96 MBT 3 pH 9.6 Ca+ 80 Alk MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 0 @ 3530.00000 0 @ 3530.00000 0.0 TRIP GAS CUTTING GAS 0 @ 3530.00000 0 @ 3530.00000 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 0 @ 3530.00000 0 @ 3530.00000 0.0 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 3530.00000 0 @ 3530.00000 0.0 AVG PROPANE (C-3) 0 @ 3530.00000 0 @ 3530.00000 0.0 CURRENT BUTANE (C-4) 0 @ 3530.00000 0 @ 3530.00000 0.0 CURRENT BACKGROUND/AVG PENTANE (C-5) 0 @ 3530.00000 0 @ 3530.00000 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Restepped 5 inch test plug and tested. Rigged down all test equipment and rigged up casing pressure test equipment. Test for thirty minutes at 2900 psi. Bleed off all pressure and open blind rams, and drain BOP stack. Blown down kill line and reset topdrive torque. Strap tally drill pipe. Rig up floor and derrick to pick up 100 joints of drill pipe. Run in hole. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3077.00 REPORT BY HARRY E. BLEYS Hillcorp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT Falls Creek #6 REPORT FOR Dout Yessack/James Lott DATE Oct 28, 5019 DEPTH 3530 PRESENT OPERATION TIME 23:59:59 YESTERDAY 3530 24 HOUR FOOTAGE 0 CASING INFORMATION 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 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 0.0 @ 3530.00000 0 @ 3530.00000 0.0 59.57127 FT/HR SURFACE TORQUE 0 @ 3530.00000 0 @ 3530.00000 0.0 9940.33984 AMPS WEIGHT ON BIT 0 @ 3530.00000 0 @ 3530.00000 0.0 14.43000 KLBS ROTARY RPM 0 @ 3530.00000 0 @ 3530.00000 0.0 73.44000 RPM PUMP PRESSURE 0 @ 3530.00000 0 @ 3530.00000 0.0 1949.26001 PSI DRILLING MUD REPORT DEPTH 3530' MW 9.1 VIS 57 PV 11 YP 20 FL 5 Gels 7/9/11 CL- 33000 FC 1/- SOL 4 SD OIL /96 MBT 3 pH 9.6 Ca+ 80 Alk MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 0 @ 3530.00000 0 @ 3530.00000 0.0 TRIP GAS CUTTING GAS 0 @ 3530.00000 0 @ 3530.00000 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 0 @ 3530.00000 0 @ 3530.00000 0.0 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 3530.00000 0 @ 3530.00000 0.0 AVG PROPANE (C-3) 0 @ 3530.00000 0 @ 3530.00000 0.0 CURRENT BUTANE (C-4) 0 @ 3530.00000 0 @ 3530.00000 0.0 CURRENT BACKGROUND/AVG PENTANE (C-5) 0 @ 3530.00000 0 @ 3530.00000 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Finished welding in sub, and finalized steam project. Hung and plumbed heater on rig floor. Set and pin roof on mud tanks. Cut new holes for wind walls to hang . Brought test plug, wear bushing, and 5 inch test joint to rig floor. Finished steam hard line to pit module #1. Fabricated and installed 1 inch air line. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3077.00 REPORT BY HARRY E. BLEYS Hillcorp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT Falls Creek #6 REPORT FOR Don Yessak / Mike Leslie DATE Oct 27, 2014 DEPTH 3530' PRESENT OPERATION Working in substructure with steam headers and returns to cellar. TIME 23:59:59 YESTERDAY 3530' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 72' 9.625"@3530' 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 2 12.25" PDC FX66M 12X9 3530' 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 3530' MW 9.1 VIS 57 PV 11 YP 19 FL 5 Gels 6/9/12 CL- 33000 FC 1/- SOL 4 SD OIL /96 MBT 1 pH 9.5 Ca+ 80 Alk 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 INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continue to plumb in steam lines to cellar and cellar. Weld pipe clamps to cellar and pits for new steam lines. Weld heater mounts to rig floor and continue with rig services and house cleaning. build two inch return lines from pit to pump and pump to boiler. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3077.00 REPORT BY HARRY E. BLEYS Hillcorp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT Falls Creek #6 REPORT FOR Don Yessak / Mike Leslie DATE Oct 26, 2014 DEPTH 3530' PRESENT OPERATION Working on Steam system. TIME 23:59:59 YESTERDAY 3530' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 72' 9.625"@3530' 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 2 12.25" PDC FX66M 12X9 3530' 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 3530' MW 9.1 VIS 56 PV 10 YP 21 FL 5 Gels 6/9/11 CL- 32000 FC 1/- SOL 4 SD OIL /96 MBT 2 pH 9.6 Ca+ 80 Alk 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 INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continue to plumb in steam lines in hopper house, pump #3.in steam lines to pits, and to heat coil for shale take. Installed steam heaters in pits and mounted new steam brackets and heater mounts with R&D welding. Fabricate and install jumper hoses as needed. Fabricate and install one inch hard line to choke for blowing down choke manifold. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3077.00 REPORT BY HARRY E. BLEYS Hillcorp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT Falls Creek #6 REPORT FOR Don Yessak / MIKE LESLIE DATE Oct 25, 2014 DEPTH 3530' PRESENT OPERATION Winterizing rig. TIME 23:59:59 YESTERDAY 3530' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 72' 9.625"@3530' 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 2 12.25" PDC FX66M 12X9 3530' 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 3530' MW 9.1 VIS 56 PV 10 YP 21 FL 5 Gels 6/9/11 CL- 32000 FC 1/- SOL 4 SD OIL /96 MBT 2 pH 9.6 Ca+ 80 Alk 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 INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Finished nippling up. Rigged up choke, and installed fittings and rigged up koomey lines to BOP. Installed stack bolts and rigged up catch can, bell nipple, flow line, hole file line and two inch bleed off line. Rigged up gas buster dump line and welded a brace in place. Layed down bridle lines and rigged up bails and elevators. Commenced working on steam heat system for rig. Closed doors on sub and hang tarps. Fixed lights in derrick and rehung service loop sock. Began general house keeping, and began winterizing rig by fabricating steam coils for cutting box. and fabricated hard line steam header for all three mud pits. CANRIG PERSONNEL ON BOARD .4 DAILY COST $3077.00 REPORT BY HARRY E. BLEYS Hillcorp Alaska, LLC Ninilchik Unit DAILY WELLSITE REPORT Falls Creek #6 REPORT FOR Don Yessak / Shane Barber DATE Oct 23, 2014 DEPTH 3530' PRESENT OPERATION Changing out Rams. TIME 23:59:59 YESTERDAY 3530' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 72' 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 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 No mud data. MW VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ Alk 0.8 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 20 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 INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Nipple up multi bowl well head and install pack off p-seal and test to 3 thousand psi for 15 minutes, while staging BOP stack in cellar. Install cellar doors. Continue to clean pits getting ready for KLA Shield mud. Performed a rig service on draw works. Check oil levels on top drive. Nipple up Top Rams and remove shipping beans. Nipple up mud cross,blind rams, and top rams. Nipple up choke and kill lines and install flow nipple, catch can, flow line, bleeder line, trip tank hose, and cross chain to stack. CANRIG PERSONNEL ON BOARD 4 DAILY COST $3077.00 REPORT BY HARRY E. BLEYS Hillcorp Alaska, LLC DAILY WELLSITE REPORT Falls Creek #6 REPORT FOR Don Yessak / Shane Barber DATE Oct 23, 2014 DEPTH 3530' PRESENT OPERATION WORKING ON CEMENT JOB. TIME 23:59:59 YESTERDAY 3530' 24 HOUR FOOTAGE 0' CASING INFORMATION 16" @ 72' 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 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 No mud data. MW VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ Alk 0.8 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 20 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 INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Ran remaining 44 joints of 9 5/8 inch casing. Landed the casing and rigged down casing crew. Circulated and conditioned mud and rigged up cementing equipment and held a pre job safety meeting. At present performing cement job. Max gas was 20 u. of trip gas. CANRIG PERSONNEL ON BOARD 4 DAILY COST $ 3157.0 REPORT BY HARRY E. BLEYS Hillcorp Alaska, LLC DAILY WELLSITE REPORT Falls Creek #6 REPORT FOR Don Yessak / Shane Barber DATE Oct 22, 2014 DEPTH 3530' PRESENT OPERATION POOH TIME 2359 YESTERDAY 3310' 24 HOUR FOOTAGE 220' CASING INFORMATION 16" @ 72' 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" PDC 12038267 9x12 72 3530 3458 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 220.7 @ 3310' 6.7 @ 3498' 61.1 59.57 FT/HR SURFACE TORQUE 12767 @ 3474' 1245 @ 3442' 9049.5 9940.33 AMPS WEIGHT ON BIT 16 @ 3525' 1 @ 3446' 10.8 14.43 KLBS ROTARY RPM 84 @ 3378' 1 @ 3435' 58.3 73.44 RPM PUMP PRESSURE 1993 @ 3516' 1656 @ 3310' 1841.5 1949.260 PSI DRILLING MUD REPORT DEPTH MW 9.0 VIS 176 PV 45 YP 47 FL 5.4 Gels 27/38/42 CL- 200 FC 2/- SOL 3 SD 1 OIL /97 MBT 16 pH 9.4 Ca+ 80 Alk 0.8 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 109 @ 3354' 8 @ 3501' 54.0 TRIP GAS CUTTING GAS 0 @ 3530' 0 @ 3530' 0.0 WIPER GAS 50+ CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 21149 @ 3354' 1673 @ 3501' 9988.0 CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG 54 PROPANE (C-3) @ @ CURRENT Pumps off BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG N/A PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Drilled ahead with 12K WOB, 80 GPM, 1800psi SPP, rotating 100rpm and 65-100 ft/hr ROP to 3530' TD. Short tripped with no issues and circulated a sweep when back on bottom. Continued circulating, pumped slug and POOH at time of report. CANRIG PERSONNEL ON BOARD 2 DAILY COST $ 2148.5 REPORT BY D Muller Hillcorp Alaska, LLC DAILY WELLSITE REPORT Falls Creek #6 REPORT FOR DATE Oct 21, 2014 DEPTH 3310' PRESENT OPERATION Drilling Ahead TIME 23:59 YESTERDAY 2121' 24 HOUR FOOTAGE 1189' CASING INFORMATION 16" @ 72' 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" PDC 12038267 9x12 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 678.3 @ 3246' 1.2 @ 2429' 103.1 220.72 FT/HR SURFACE TORQUE 12024 @ 3260' 1162 @ 2812' 5743.0 10378.48 AMPS WEIGHT ON BIT 19 @ 3276' 0 @ 2989' 9.6 9.81 KLBS ROTARY RPM 86 @ 3247' 0 @ 3263' 41.7 0.0 RPM PUMP PRESSURE 1942 @ 3056' 1414 @ 2167' 1732.1 1656.63 PSI DRILLING MUD REPORT DEPTH MW 9.0 VIS 170 PV 50 YP 50 FL 6.3 Gels 29/54/74 CL- 200 FC 2/- SOL 3 SD 1 OIL /97 MBT 14 pH 9.3 Ca+ 80 Alk 0.8 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 155 @ 2947' 7 @ 2460.00000 48.7 TRIP GAS CUTTING GAS 0 @ 3310' 0 @ 3310.00000 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 29940 @ 2947' 1268 @ 2460.00000 8619.5 CONNECTION GAS HIGH ETHANE (C-2) @ @ AVG 49 PROPANE (C-3) @ @ CURRENT 69 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 20 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Drill ahead to 1979'. CBU. Pump sweep. Wiper trip to 319'. Service rig. RIH. Drill ahead - WOB 13 RPM 80 TQ 8-10K GPM 570 SPP 1780 CANRIG PERSONNEL ON BOARD 2 DAILY COST $ 2148.5 REPORT BY D Muller Hillcorp Alaska, LLC DAILY WELLSITE REPORT Falls Creek #6 REPORT FOR Mike Leslie / Shane Barber DATE Oct 21, 2014 DEPTH 2021' PRESENT OPERATION Drilling ahead TIME 23:59 YESTERDAY 537' 24 HOUR FOOTAGE 1484' CASING INFORMATION 16" @ 72' 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" PDC 12038267 9x12 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 625.3 @ 1662' 3.2 @ 1348' 154.4 91 FT/HR SURFACE TORQUE 8859 @ 1828' 1243 @ 748' 4715.8 8030.72 AMPS WEIGHT ON BIT 15 @ 1702' 0 @ 1439' 7.3 8.93000 KLBS ROTARY RPM 84 @ 1821' 0 @ 2056' 31.0 77.1 RPM PUMP PRESSURE 1714 @ 1808' 1123 @ 1538' 1449.1 1620 PSI DRILLING MUD REPORT DEPTH MW 9.0 VIS 56 PV 50 YP 51 FL 13.6 Gels 29/53/74 CL- 300 FC 2/- SOL 3 SD 0.25 OIL /97 MBT 20 pH 9.7 Ca+ 80 Alk 1.1 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 64 @ 2120' 1 @ 791' 12.6 TRIP GAS CUTTING GAS 0 @ 2121' 0 @ 2121' 0.0 WIPER GAS 24 CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) @ 2120' 154 @ 659' 2206.5 CONNECTION GAS HIGH N/A ETHANE (C-2) @ @ AVG 13 PROPANE (C-3) @ 0 @ CURRENT 16 BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 3 PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Drilled to 1979' . Short trip to Collars. TIH and continue drilling. Trip gas 24 u. Off bottom 5.5 hrs. CANRIG PERSONNEL ON BOARD 2 DAILY COST $ 2148.50 REPORT BY D Muller Hillcorp Alaska, LLC DAILY WELLSITE REPORT Falls Creek #6 REPORT FOR Mike Leslie / Shane Barber DATE Oct 19, 2014 DEPTH 537' PRESENT OPERATION Drilling ahead TIME 23:59 YESTERDAY 72' 24 HOUR FOOTAGE 465' CASING INFORMATION 16" @ 72' 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" PDC 12038267 9x12 72' 465' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 671 @ 83' 0.9 @ 354' 150.5 198.6 FT/HR SURFACE TORQUE 9064 @ 133' 2850 @ 73' 3367.1 5168 AMPS WEIGHT ON BIT 25 @ 76' 0 @ 163' 2.8 4.93 KLBS ROTARY RPM 78 @ 404' 1 @ 112' 14.3 13.56 RPM PUMP PRESSURE 1289 @ 485' 519 @ 77' 972.8 1210.26 PSI DRILLING MUD REPORT DEPTH MW 8.9 VIS 213 PV 46 YP 49 FL - Gels 25/47/68 CL- 300 FC 2/- SOL 3 SD 0.25 OIL /97 MBT 24 pH 9.6 Ca+ 80 Alk 1.1 MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 0 @ 0 0 @ 0 0 TRIP GAS 0 CUTTING GAS 0 @ 0 0 @ 0 0 WIPER GAS 0 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C-1) 0 @ 0 0 @ 0 0 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 0 0 @ 0 0 AVG 0 PROPANE (C-3) 0 @ 0 0 @ 0 0 CURRENT 0 BUTANE (C-4) 0 @ 0 0 @ 0 0.0 CURRENT BACKGROUND/AVG 0 PENTANE (C-5) 0 @ 0 0 @ 0 0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Gas monitoring only DAILY ACTIVITY SUMMARY Finish rigging up. Pick up 5" drill pipe. Pick up mud motor and CANRIG PERSONNEL ON BOARD 2 DAILY COST REPORT BY D Muller