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214-177
DATE 11/19/2019 Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: doudean@hilcorp.com To: AOGCC Natural Resources Technician 333 W. 71h Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL SCU 41B-04 (214-177) Production Profile 15 OCT 2018 CD: ANALYSIS FIELD DATA 1 1 1141201 8 2:16 PM 1113'2518 2:16 PPA Fife folder File folder 214177 3 145 8 RECEIVED NOV 19 2019 AOGCC Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: ��/� V --)Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ECEIVED JAN 31 2019 1. Operations Abandon LJ Plug Perforations LJ Fracture Stimulate LJ Pull Tubing Li t u w Li Performed: Suspend ❑ Perforate 1] Other Stimulate ❑ Alter Casin g ❑ Change Approved Program ❑ Plug for Reddll ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2. Operator Hilcorp Alaska, LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development Q Stratigraphic❑ Exploratory ❑ Service ❑ 214-177 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-133-10109-03-00 7. Property Designation (Lease Number): 8. Well Name and Number: A028997 Soldotna Creek Unit (SCU) 41 B-04 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Swanson River Field / Hemlock Oil 11. Present Well Condition Summary: Total Depth measured 11,003 feel Plugs measured N/A feet true vertical 10,829 feet Junk measured 10,854' (fish) feet Effective Depth measured 10,870 feet Packer measured 8,807 feet true vertical 10,716 feet true vertical 8,807 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 22' 22" 22' 22' Surface 3,000' 13-3/8" 3,000' 3,000' 2,730 psi 1,130 psi Intermediate Production 9,055' 7" 9,055' 9,055' 6,340 psi 3,830 psi Liner 2,154' 4-1/2" 10,998' 10,826' 8,430 psi 7,500 psi Perforation depth Measured depth See Attached Schematic" True Vertical depth See Attached Schematic— Tubing (size, grade, measured and true vertical depth) 3-1/2" 9.3# / L-80 8,836' MD 8,836' TVD Packers and SSSV (type, measured and true vertical depth) Hydraulic Pkr; N/A 8,807' MD 8,807' TVD N/A; N/A 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: 126 4811 75 450 225 Subsequent to operation: 92 4665 100 410 240 14. Attachments (required per 20 AAC 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations Q Exploratory[] Development Q 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: 318-108 / 318-182 Authorized Name: Bo York 777-8345 Contact Name: Taylor Nasse Authorized Title: Operations Manager Contact Email: 82se22221D.20m tn Authorized Signature: Date: 1 .,1 T fir+ U 11 Contact Phone: 777-8354 Form 10-404 Revised 4/20172 • 1 1 Submit Original Only �RBDM ER o I ,,o SCANNEr 15 2019 Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 41B-04 E-line 50-133-10109-03-00 1 214-177 11/26/18 1 1/17/19 Daily Operations: 11/26/2018 - Monday Sign in. Wait on right lubricator to come from shop. PTW and JSA. Rig up lubricator. PT to 250 psi low and 3,500 psi high. TP 1500 psi, RIH w/ 2-1/2" x 8' HC, 6 spf, 60 deg phase. Tie into log from town. Run correlation log and send to town. Told was 5' low. Ran another log and send to town. Got ok to pert from 10,579' to 10,587' after flowing well down to 1,000 psi. Bled well to 1,000 psi and fired gun. Lost 650 psi and then gain back to 1,300 psi and to 1,500 psi as soon as we got back in tubing. POOH, Rig down equipment and turn well back to field. 12/14/2018 - Friday Sign in. Mobe to location. PTW and JSA. Shut well in. Spot equipment and rig up lubricator. PT to 250 psi low and 3,500 psi high. TP - 1,450 psi. Arm gun. RIH w/ 2-1/2" x 12' Razor HC, 6 spf, 60 deg phase and tie into AKE-Line pert log dated 11-26- 18. Run correlation log and send to town. Town said log was on but changed perf depth to 10,450' to 10,462'. Spotted and fired shot with 1,500 psi on well. Pressure went to 1,520 psi when gun was fired. After 5 min - 1,525 psi and stayed there for 15 min. POOH. All shots fired. Rig down equipment and turn well over to field. 01/17/19 - Thursday RU slickline, PT to 2,500 psi. RIH w/ scratcher to 3,000', no obstruction. POOH. RIH w/ helix cutter to 3,000', no obstruction. POOH. RIH w/ gauge ring to 10,796' tag fill. POOH. RDMO. Hiloorp Alaska, LLC KB -THF: 18.00' GL = 173.7' AMSL 22 Q 1 1 2 13 I i M D2,OO2' SCHEMATIC dixlwi Fel�7yf±1II Swanson River Unit Well: SCU 41B-04 Completion Ran 1/29/15 PTD: 214-177 API: 50-133-10109-03 Size Type Wt Grade Conn. ID Top Btm 22" Conductor 2 - 2.992" - Surf 22' 13-3/8" Surf. Csg 54.5 J-55 STC 12.615" Surf 3,000' 7" Production Casing 29 N-80 BTC 6.184" Surf 304' 26 N-80 BTC 6.276" 304' 1,235' 23 N-80 BTC 6.366" 1,235' 4,229' 26 N-80 BTC 6.276" 4,229' 4,527' 29 N-80 LTC 6.184" 4,527' 6,489' 26N-80 LTC 6.276" 6,489' 9,055' 4-1/2" Production Liner 12.6 L-80 DWC/C-HT 1 3.958" 1 8,842' 10,998' �� I TUBING 3-1/2" Production Tubing 9.3 L-80 8RD 2.992 0' 8,836' JEWELRY DETAIL 5i 61 E 8 9 le 7" CBL (2/03/15) - 9,784' rf" RA Mrk Jt 1 RA Mrk Jt RA Mrk Jt DV Collar 6,944' G-1 H-1 H-3 b H-6 H-7 RAMrkJt 11_9 11 12 6" Ho No. Depth ID OD Item 1 18' 2.950" - Tubing Hanger, 3-1/2" SRD Box x 3-1/2" BIRD Box 2 19' 2.992" 3.500" Pups, 3-1/2" BIRD 3 3,994' 2.992" 5.250" 3-1/2" SFO -1 Mandrel BIRD GLV #4 (Dummy) 4 4,893' 2.992" 5.250" 3-1/2" SFO -1 Mandrel BIRD GLV n3 (Live Valve) 5 8,625' 2.992" 5.250" 3-1/2" SFO -1 Mandrel BIRD GLV rig (Dummy) 6 8,732' 2.992" 5.250" 3-1/2" SFO -1 Mandrel BIRD GLV #1(Orijlce Valve) 7 8,784' 2.992" 5.250" Chemical Injection Mandrel (Live Valve, 3,000psn 8 8,807' 3.000' 5.875" Hydraulic Packer 9 8,827' 2.813" 10,470 10,477' 10 8,836' 2.992" 41.N.2." 21 -.1', WL Entry Guide 31 10,854' - - Fish-Gaslik Dummy Valve (Lost 2/04/15) 12 10,854' - - Fish- Gaslift Dummy Valve (Lost 2/01/15) Short RA Marker Joints @ 10,346'-70,359' MD @ 10,547'-10,561' MD @ 10,680'-10,694' MD @ 10,772'-10,786' MD PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date G-1 10,300' 10,320' 10,238' 10,255' 20 6 2-1/2" Connex 05/06/18 H-1 10,405' 10,410' 10,326' 10,330' 5 6 2-1/2" Connex 03/27/18 H-1/11-2 10,410' 10,430' 10,330 10,346' 20 6 2-1/2" Connex 03/29/18 H-3 10,450' 10,462' 10,363' 10,373' 12 6 2-1/2" Connex 12/14/18 H-6 10,579' 10,587' 10,470 10,477' 8 6 2-1/2" Connex 11/26/18 H-7 10,607' 10,642' 10,494' 10,523' 35 6 2-1/2" Connex 06/02/15 H-9 10,725' 10,777' 10,593' 10,637' 52 6 2-1/2" Connex 02/04/15 WELL DATA PTD: 214-177 API: 50-133-10109-03 Lease: FEDA-028997 Spud Date: 12/24/2014 Tree cxn: 3.5" Bowen Lift Threads: 3-1/2" 8RD Tag PBTD @ 10,854'S LM 2.50" Gauge Ring le 1/2 2/01/15 Max Deviation 34' @ 10,402' TD =11,003' MD -10,829' TVD PBTD =10,870' MD- 30,716' TVD Max Dogleg 10.8'/100' Downhole Revised: 2/04/15 Updated by DMA 01-30-19 WELL DATA PTD: 214-177 API: 50-133-10109-03 Lease: FEDA-028997 Spud Date: 12/24/2014 Tree cxn: 3.5" Bowen Lift Threads: 3-1/2" 8RD RECERPD STATE OF ALASKA ASA OIL AND GAS CONSERVATION COISION REPORT OF SUNDRY WELL OPERATIONS MAY 018 1.Operations Abandon Li Plug Perforations Li Fracture Stimulate Li Pull Tubing L AOGOGin U Performed: Suspend ElPerforate 0 Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ srforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: , Name: Hilcorp Alaska,LLC lorato❑ment Develo 2 Exploratory P rY ❑ 214-177 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic El Service ❑ 6.API Number: AK 99503 50-133-10109-03-00 7.Property Designation(Lease Number): 8.Well Name and Number: A028997 Soldotna Creek Unit(SCU)41 B-04 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Swanson River Field/Hemlock Oil 11.Present Well Condition Summary: Total Depth measured 11,003 feet Plugs measured N/A feet true vertical 10,829 feet Junk measured 10,854'(fish) feet Effective Depth measured 10,870 feet Packer measured 8,807 feet true vertical 10,716 feet true vertical 8,807 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 22' 22" 22' 22' Surface 3,000' 13-3/8" 3,000' 3,000' 2,730 psi 1,130 psi Intermediate Production 9,055' 7" 9,055' 9,055' 6,340 psi 3,830 psi Liner 2,154' 4-1/2" 10,998' 10,826' 8,430 psi 7,500 psi Perforation depth Measured depth See Attached Schematic** ?JUN 2 1 Lu1I True Vertical depth See Attached Schematic"' Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3#/L-80 8,836'MD 8,836'TVD Packers and SSSV(type,measured and true vertical depth) Hydraulic Pkr;N/A 8,807'MD 8,807'TVD N/A;N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: **PLEASE NOTE: Remaining perfs from 10-403 Sundry 318-108(appear as "purple"on the schematics)may be shot after drilling of new gas injection well(per telecon G Schwartz/T Kramer 04-26-18). 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 149 4819 54 0 250 Subsequent to operation: 149 3773 56 575 200 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 2 Exploratory❑ Development❑, Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑✓ Gas ❑ 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: 318-182 Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer@hilcorp.com Authorized Signature: (�C%lG Gs Date: 5/3,//g Contact Phone: 777-8420 Form 10-404 Revis MLOM��+r"' MAY 3 0 2010 RBDMS�_ it v � � `� j Submit Original Only Orn' • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 41B-04 E-Line 50-133-10109-03 214-177 5/6/18 5/6/18 Daily Operations: 05/06/2018-Sunday Sign in. Mobe to location. Shut well in. Rig up lubricator. PT to 250 psi low and 3,000 psi high. RIH w/2-1/2" x 20' Connex HC, 6 spf, 60 deg phase and tie into OHL. Run correlation log and send to town. Told to downshift log 2'. Downshifted log 2' and logged up to stop depth at 10,290.7' (9.3' CCL/GR to Top Shot) . Fired gun from 10,300' to 10,320' with 825 psi on tubing. After 5 min - 850 psi, 10 min - 875 psi and 15 min - 900 psi. POOH.All shots fired and tubing pressure was 1,000 psi. Rig down equipment and turn well back over to field. 6 Swanson River Unit Well: SCU 41B-04 H . SCHEMATIC Completion Ran 1/29/15 PTD: 214-177 Hilcorp Alaska,LLC API: 50-133-10109-03 KB-THF: 18.00' GL= 173.7'AMSL CASING DETAIL I Size Type Wt Grade Conn. ID Top Btm 22'' I 1 2 � 22" Conductor - - - Surf 22' 13-3/8" Surf.Csg 54.5 J-55 STC 12.615" Surf 3,000 DV Collar 29 N-80 BTC 6.184" Surf 304' " 2,002' 26 N-80 BTC 6.276" 304' 1,235' 7" Production Casing 23 N-80 BTC 6.366" 1,235' 4,229' 26 N-80 BTC 6.276" 4,229' 4,527' 13-3/8" 29 N-80 LTC 6.184" 4,527' 6,489' tr 26 N-80 LTC 6.276" 6,489' 9,055' 4-1/2" Production Liner 12.6 L-80 DWC/C-HT 3.958" 8,842' 10,998' 31 10 1 TUBING 3-1/2" Production Tubing 9.3 L-80 8RD 2.992 0' 8,836' JEWELRY DETAIL No. Depth ID OD Item i, 1 18' 2.950" - Tubing Hanger,3-1/2"8RD Box x 3-1/2"8RD Box I 111 DV Collar 2 19' 2.992" 3.500" Pups,3-1/2"8RD 6,944' 3 3,994' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#4(Dummy) 4 4,893' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#3(Live Valve) 5 8,625' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#2(Dummy) I 6 8,732' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#1(Orifice Valve) 7 8,784' 2.992" 5.250" Chemical Injection Mandrel(Live Valve,3,000 psi) 8 8,807' 3.000" 5.875" Hydraulic Packer 6 x 11 9 8,827' 2.813" 4.500" X-Nipple a 10 8,836' 2.992" 4.500" WL Entry Guide 7 an i 11 10,854' - Fish-Gaslift Dummy Valve(Lost 2/04/15) 'A W 12 10,854' - Fish-Gaslift Dummy Valve(Lost 2/01/15) I I I J.-. Short RA Marker Joints 8 e ,�� @ 10,346'-10,359'MD 4. @ 10,547'-10,561'MD 9 @ 10,680'-10,694'MD @ 10,772'-10,786'MD w 10 rj PERFORATION DETAIL " 4 L Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date G-1 10,300' 10,320' 10,238' 10,255' 20 6 2-1/2"Connex 05/06/18 CBL(2/03/15) H-1 10,405' 10,410' 10,326' 10,330' 5 6 2-1/2"Connex 03/27/18 9,784' k'' k; H-1/H-2 10,410' 10,430' 10,330' 10,346' 20 6 2-1/2"Connex 03/29/18 G-1 H-2 ±10,425' ±10,445' ±10,150' ±10,167' ±20 6 ** Proposed RA Mrk Jt ` ' H-3 ±10,454' ±10,466' ±10,174' ±10,184' ±12 6 ** Proposed Rit H-1 H-5 ±10,489' ±10,564' ±10,203' ±10,265' ±75 6 ** Proposed 4 pr H-2 H-6 ±10,579' ±10,587' ±10,279' ±10,286' ±8 6 ** Proposed 20 H-3 H-7 10,607' 10,642' 10,494' 10,523' 35 6 2-1/2"Connex 06/02/15 H-5 H-7L ±10,694' ±10,705' ±10,376' ±10,385' ±11 6 ** Proposed RA Mrk Jt 111 ,? H-9 10,725' 10,777' 10,593' 10,637' 52 6 2-1/2"Connex 02/04/15 r , H-6 **PLEASE NOTE: Remaining perfs from 10-403 Sundry 318-108(appear as"purple"on the schematic PERFORATION #, `y H-7 DETAIL)may be shot after drilling of new gas iniection well(per telecon G Schwartz/T Kramer 04-26-18). RA Mrk Jt •w GLV Port Temp 0 # Size Depth TCF PSC PSO PTRO Description It 2 16 115 0.883 1183 1309 1500 IPOR-1/IPOC-1/PPOR-1 ._ H-7H RAMrkJt ` H-9 1 20 157 0.811 ORIFICE-1 1 11 1. 12 cat) Tag PBTD @ 10,854'SLM WELL DATA 4 2.50"Gauge Ring PTD:214-177 4 1/2"r,_ +t;-, 6"Hole 2/01/15 API: 50-133-10109-03 TD=11,003'MD-10,829'TVD Max Deviation 34°@ 10,402' Lease: FEDA-028997 PBTD=10,870'MD-10,716'ND Max Dogleg 10.8°/100'@ 9,068' Spud Date:12/24/2014 Tree cxn: 3.5"Bowen Downhole Revised:2/04/15 Updated by DMA 05/30/18 Lift Threads: 3-1/2"8RD P0"i'XI T s THE STA Alaska Oil and as y►."'t^'d��a� offLASKA Conservation Commission _�= 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501- 572 Main: 907.279. 433 ®F AL A.914"' Fax: 907.276. 542 www.aogcc.alaska gov Chad Helgeson Operations Manager %WEI) Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 41B-04 Permit to Drill Number: 214-177 Sundry Number: 318-182 Dear Mr. Helgeson: 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, Hollis S. French Chair DATED this 2 day of May, 2018. III IBDMSL MAY 0 3 2018 0 0 RECEIVED • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIONo� I APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ACAG 1.Type of Request: Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Repair Well ❑ avn ElSuspend ❑ Perforate 2Other Stimulate ❑ Pull Tubing El Change Approved Progrllam 0 Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other: 0 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development Q 214-177 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic El Service ❑ 6.API Number: Anchorage Alaska 99503 50-133-10109-03-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 123A Soldotna Creek Unit(SCU)41 B-04 Will planned perforations require a spacing exception? Yes ❑ No ❑✓ 9. Property Designation(Lease Number): 10. Field/Pool(s): A028997 Swanson River Field/Hemlock Oil 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): i I i 11,003' 10,829' 10,870' 10,716' 2,064 psi N/A 10,854'(fish) Casing Length Size MD TVD Burst Collapse Structural j Conductor 22' 22" 22' 22' Surface 3,000' 13-3/8" 3,000' 3,000' 2,730 psi 1,130 psi Intermediate Production 9,055' 7" 9,055' 9,055' 6,340 psi 3,830 p'i Liner 2,154' 4-1/2" 10,998' 10,826' 8,430 psi7,500 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic** See Attached Schematic** 3-1/2" 9.3#/L-80 8,836 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Hydraulic Pkr; N/A 8,807'MD/8,807'TVD;N/A 12.Attachments: Proposal Summary Q Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑r Service ❑ I 14.Estimated Date for 15.Well Status after proposed work: 5/11/2018 Commencing Operations: OIL ❑ WIND ❑ WDSPL El Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG 0 GSTOR ❑ SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown ❑ Abandoned 0 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson 777-8405 Contact Name: Taylor Nasse Authorized Title: Operations Manager Contact Email: tnasse@hilcorp.com �� �/ Contact Phone: 777-8354 Authorized Signature: (i2%'7/gi, �� Date: / LT all j? COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 1'3 Plug Integrity El BOP Test ❑ Mechanical Integrity Test 0 Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No ® Subsequent Form Required: /0 r 1 D tir II APPROVED BY Approved by: Qat ,.. COMMISSIONER THE COMMISSION Date: 'S 1/2-Itl 6 Form 10-403 Revised 4/2017 Approved applQV pLI GAffm date of aiiB MS mAtycailipmlicaantde • • . Well Prognosis Well: SCU 41B-04 Hilcora Alaska,LI) Date:4/27/2018 Well Name: SCU 41B-04 API Number: 50-133-10109-03 Current Status: Gas Lifted Producer Leg: N/A Estimated Start Date: May 11th, 2018 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-177 First Call Engineer: Ted Kramer (907) 777-8420(0) (985) 867-0665 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824(M) Current Bottom Hole Pressure: —2,859 psi @ 10,700' TVD (Based on P/T Survery on 2/5/15) Maximum Expected BHP: —2,859 psi @ 10,700' TVD (Based on P/T Survery on 2/5/15) Max.Allowable Surface Pressure: —2,064 psi (Based on P/T Survery on 2/5/15) Brief Well Summary This well wasoriginally o ginally drilled and completed with the Saxon#169 rig in February 2015 in the H-7 Sand. In June, 2015 the H-5 was added and the H-1 and H-2 was added in March 2018. The purpose of this work/sundry is to add perforations in the G-2. The proposed perforations are in the Hemlock Formation in Swanson River Unit and in accordance with Conservation Order CO123A, there are no restrictions to well spacing within the Hemlock Oil Pool between wells and this well is more than 500 feet of the external property line. Note: The remaining Hemlock perforations on Sundry#318-108 will be shot after the new gas injection Well is drilled in July 2018. E-line Procedure: 1. MIRU E-line, PT Lubricator to 3,000 psi Hi 250 Low. a. Tree connection is 3.5" Bowen. 2. RU HC wireline guns. 3. SI and bleed tubing pressure down, as directed by Reservoir Engineer. 4. RIH and perforate the following interval: Zone Sands Top (MD) Btm (MD) FT Tyonek G-2 10,300' 10,320' 20 a. Proposed perfs shown on the proposed schematic in red font. b. Final Perfs tie-in sheet will be provided in the field for exact perf interval. c. Correlate using proposed Gamma/CCL. d. Record tubing pressures before and after each perforating run. 5. POOH. RD E-line. 6. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic 4110 • Swanson River Unit Well: SCU 41B-04 SCHEMATIC Completion Ran 1/29/15 PTD: 214-177 Hilcorp Alaska,LLC API: 50-133-10109-03 KB-THF: 18.00' GL=173.7'AMSL CASING DETAIL J i Ll Size Type Wt Grade Conn. ID Top Btm 22"lJ 2 22" Conductor - - - Surf 22' 13-3/8" Surf.Csg 54.5 J-55 STC 12.615" Surf 3,000' t `; DV Collar I 29 N-80 BTC 6.184" Surf 304' `� 26 N-80 BTC 6.276" 304' 1,235' 2,002' 4 4_, 23 N-80 BTC 6.366" 1,235' 4,229' 7" Production Casing 26 N-80 BTC 6.276" 4,229' 4,527 13-3/8" 4, ei 29 N-80 LTC 6.184" 4,527' 6,489' M` 26 N-80 LTC 6.276" 6,489' 9,055' ' 4-1/2" Production Liner 12.6 L-80 DWC/C-HT 3.958" 8,842' 10,998' i_' 3 i P TUBING a► 3-1/2" Production Tubing 9.3 L-80 8RD 2.992 0' 8,836' 4 mit ' JEWELRY DETAIL 1rNo. Depth ID OD Item r 't• 1 18' 2.950" Tubing Hanger,3-1/2"8RD Box x 3-1/2"8RD Box DV Collar 2 19' 2.992" 3.500" Pups,3-1/2"8RD 6,944' 3 3,994' 2.992" 5.250" 3-1/r SFO-1 Mandrel 8RD GLV#4(Dummy) 4 4,893' 2.992" 5.250" 3 1/2"SFO-1 Mandrel 8RD GLV#3(Live Valve) 5 8,625' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#2(Dummy) 6 8,732' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#1(Orifice Valve) 51 7 8,784' 2.992" 5.250" Chemical Injection Mandrel(Live Valve,3,000 psi) 8 8,807' 3.000" 5.875" Hydraulic Packer a46i` 9 8,827' 2.813" 4.500" X-Nipple 10 8,836' 2.992" 4.500" WL Entry Guide 7 11 10,854' - Fish-Gaslift Dummy Valve(Lost 2/04/15) an Fir::,' 12 10,854' Fish-Gaslift Dummy Valve(Lost 2/01/15) 8 Short RA Marker Joints @ 10,346'-10,359'MD k l „r @ 10,547'-10,561'MD 9 El '; @ 10,680-10,694'MD 2@ 10,772'-10,786'MD 10 I PERFORATION DETAIL -- ' k Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date H-1 10,405' 10,410' 10,326' 10,330' 5 6 2-1/2"Connex 03/27/18 CBL(2/03/15) ; ,..P. H-1/H-2 10,410' 10,430' 10,330' 10,346' 20 6 2-1/2"Connex 03/29/18 9,784' ,a f H-2 ±10,425' ±10,445' ±10,150' ±10,167' ±20 6 ** Proposed " ' H-3 ±10,454' ±10,466' ±10,174' ±10,184' ±12 6 ** Proposed RAMrkJt H-5 ±10,489' ±10,564' ±10,203' ±10,265' ±75 6 ** Proposed Er H-1 H-6 ±10,579' ±10,587' ±10,279' ±10,286' ±8 6 ** Proposed H-2 H-7 10,607' 10,642' 10,494' 10,523' 35 6 2-1/2"Connex 06/02/15 'IL as H-3 H-7L ±10,694' ±10,705' ±10,376' ±10,385' ±11 6 ** Proposed g H-5 H-9 10,725' 10,777' 10,593' 10,637' 52 6 2-1/2"Connex 02/04/15 RA Mrk Jt 4 H-6 **PLEASE NOTE: Remaining perfs from 10-403 Sundry 318-108(appear as"purple"on the schematic PERFORATION ttt DETAIL)may be shot after drilling of new gas iniection well(per telecon G Schwartz/T Kramer 04-26-18). 1,." H-7 'r' GLV Port Temp RA Mrk Jt ,.` Ir # Size Depth TCF PSC PSO PTRO Description 621, r`" H-7L 16 115 0.883 1183 1309 1500 IPOR-1/IPOC-1/PPOR-1 RA Mrk Jt 11-9 El 20 157 0.811 ORIFICE-1 11 •r 12 Tag PBTD @ 10,854'SLM WELL DATA i‘i tii 2.50"Gauge Ring N. - 6"Hole 2/01/15 PTD:214-177 4-1/2" '<"r API: 50-133-10109-03 TD=11,003'MD-10,829'TVD Max Deviation 34°@ 10,402' Lease: FEDA-028997 PBTD=10,870'MD-10,716'TVD Max Dogleg 10.8'/100'@ 9,068' Spud Date:12/24/2014 Tree cxn: 3.5"Bowen Downhole Revised:2/04/15 Updated by DMA 04/27/18 Lift Threads: 3-1/2"8RD • • Swanson River Unit 11 Well: SCU 41B-04 PROPOSED SCHEMATIC Completion Ran 1/29/15 PTD: 214-177 Hilcorp Alaska,LLC API: 50-133-10109-03 KB-THF: 18.00' GL=173.7'AMSL CASING DETAIL ci 1 l Size Type Wt Grade Conn. ID Top Btm 22"� kA 2 �l 22"Conductor Surf 22' 13-3/8" Surf.Csg 54.5 1-55 STC 12.615" Surf 3,000' DV Collar 29 N-80 BTC 6.184" Surf 304' 2,002' 26 N-80 BTC 6.276" 304' 1,235' 7" Production Casing 23 N 80 BTC 6.366" 1,235' 4,229' t 26 N-80 BTC 6.276" 4,229' 4,527' 13-3/8" ,. 29 N-80 LTC 6.184" 4,527' 6,489' 26 N-80 LTC 6.276" 6,489' 9,055' d 4-1/2" Production Liner 12.6 L-80 DWC/C-HT 3.958" 8,842' 10,998' it 3 MI ;, TUBING 3-1/2" Production Tubing 9.3 L-80 8RD 2.992 0' 8,836' g 4 4 JEWELRY DETAIL No. Depth ID OD Item 1 18' 2.950" - Tubing Hanger,3-1/2"8RD Box x 3-1/2"8RD Boxiorv"" x DV Collar 2 19' 2.992" 3.500" Pups,3-1/2"8RD 6,944' 3 3,994' 2.992" 5.250" 3 1/2"SFO 1 Mandrel 8RD GLV#4(Dummy) A 4 4,893' 2.992" 5.250" 3-1/2"SFO 1 Mandrel 8RD GLV#3(Live Valve) V r 5 8,625' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#2(Dummy) r. 6 8,732' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#1(Orifice Valve) 5 7 8,784' 2.992" 5.250" Chemical Injection Mandrel(Live Valve,3,000 psi) ) i , 8 8,807' 3.000" 5.875" Hydraulic Packer 6 ilii 1' 9 8,827' 2.813" 4.500" X-Nipple J 11 ( 10 8,836' 2.992" 4.500" WL Entry Guide 7 11 10,854' - - Fish-Gaslift Dummy Valve(Lost 2/04/15) a 12 10,854' Fish-Gaslift Dummy Valve(Lost 2/01/15) orl I V., I t Short RA Marker Joints 8 @ 10,346'-10,359'MD @ 10,547'-10,561'MD 9 E [ @ 10,680'-10,694'MD �, @ 10,772'-10,786'MD r1 10 .I'/� PERFORATION DETAIL 7„ Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date .a: ��✓ ±10,300' ±10,320' 10,238' 10,255' 20 6 TBD Proposed ,r,"-, H-1 10,405' 10,410' 10,326' 10,330' 5 6 2-1/2"Connex 03/27/18 CBL(2843/15). u ; H-1/H-2 10,410' 10,430' 10,330' 10,346' 20 6 2-1/2"Connex 03/29/18 9,784' r G-1 H-2 ±10,425' ±10,445' ±10,150' ±10,167' ±20 6 ** Proposed RA Mrk Jt4VIP H-3 ±10,454' ±10,466' ±10,174' ±10,184' ±12 6 ** Proposed 4 ph H-1 H-5 ±10,489' ±10,564' ±10,203' ±10,265' ±75 6 ** Proposed k F4' 11-2 H-6 ±10,579' ±10,587' ±10,279' ±10,286' ±8 6 ** Proposed kVai H-3 H-7 10,607' 10,642' 10,494' 10,523' 35 6 2-1/2"Connex 06/02/15 .,,, H-5 H-7L ±10,694' ±10,705' ±10,376' ±10,385' ±11 6 ** Proposed sli RA Mrk Jt H-9 10,725' 10,777' 10,593' 10,637' 52 6 2-1/2"Connex 02/04/15 , 11-6 5 ;t **PLEASE NOTE: Remaining perfs from 10-403 Sundry 318-108(appear as"purple"on the schematic PERFORATION yl 1,,';', H-7 DETAIL)may be shot after drilling of new gas iniection well(per telecon G Schwartz/T Kramer 04-26-18). GLV Port Temp @ RA Mrk Jt 0 Ir NA # Size Depth TCF PSC PSO PTRO Description RE r H-7H 16 115 0.883 1183 1309 1500 IPOR-1/IPOC-1/PPOR-1 RA Mrk Jt 101 : 11-9 20 157 0.811 ORIFICE-1 11 „ 12 Tag PBTD @ 10,854'SLM WELL DATA 2.50"Gauge Ring ®,r '-.1. Nt 6"Hole 2/01/15 PTD:214-177 4-1/2" API: 50-133-10109-03 TD=11,003'MD-10,829'ND Max Deviation 34°@ 10,402' Lease: FEDA-028997 PBTD=10,870'MD-10,716'ND Max Dogleg 10.8°/100'@ 9,068' Spud Date:12/24/2014 Tree cxn: 3.5"Bowen Downhole Revised:2/04/15 Updated by DMA 04/27/18 Lift Threads: 3-1/2"8RD STATE OF AKA OIL AND GAS CONSERVATION COASION E • REPORT OF SUNDRY WELL OPERATIONS APR Z? Nig1.Operations Abandon LI Plug Perforations U Fracture Stimulate U Pull Tubing U Op ati s wn Performed: Suspend 1=1Perforate ❑ Other Stimulate ❑ Alter Casing 1:1Char� i $m ❑ Plug for Redrill CIrforate New Pool E] Repair Well CI Re-enter Susp Well❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development Q Exploratory ❑ 214-177 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic❑ Service ❑ 6.API Number: AK 99503 50-133-10109-03-00 7.Property Designation(Lease Number): 8.Well Name and Number: A028997 Soldotna Creek Unit(SCU)41B-04 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Swanson River Field/Hemlock Oil 11.Present Well Condition Summary: Total Depth measured 11,003 feet Plugs measured N/A feet true vertical 10,829 feet Junk measured 10,854'(fish) feet Effective Depth measured 10,870 feet Packer measured 8,807 feet true vertical 10,716 feet true vertical 8,807 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 22' 22" 22' 22' Surface 3,000' 13-3/8" 3,000' 3,000' 2,730 psi 1,130 psi Intermediate Production 9,055' 7" 9,055' 9,055' 6,340 psi 3,830 psi Liner 2,154' 4-1/2" 10,998' 10,826' 8,430 psi 7,500 psi Perforation depth Measured depth See Attached Schematic** ��° True Vertical depth See Attached Schematic** Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3#/L-80 8,836'MD 8,836'TVD Packers and SSSV(type,measured and true vertical depth) Hydraulic Pkr;N/A 8,807'MD 8,807'TVD N/A;N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: ""PLEASE NOTE: Remaining perfs from 10-403 Sundry 318-108(appear as "purple"on the schematics)may be shot after drilling of new gas injection well(per telecon G Schwartz/T Kramer 04-26-18). 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 108 142 72 0 200 Subsequent to operation: 149 4819 54 0 250 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations CI Exploratory❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR El WINJ ❑ WAG ❑ GINJ ❑ SUSP El 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: 318-108 Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer hilcoro.com Authorized Signature: (r../4/rro Date: Contact Phone: 777-8420 Form 10-404 Revised 4/2017 - 51/,/' RBDMS ,MAI 0 12010 Submit Original Only • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 41B-04 E-Line 50-133-10109-03 214-177 3/27/18 3/29/18 Daily Operations: 03/27/2018 -Tuesday PTW and JSA. Mobe to location. Spot equipment. Rig up lubricator and pressure test to 250 psi low and 3000 psi high. Shut well in. RIH w/2-1/2"x20' (5' loaded from bottom) Connex HC, 6 spf, 60 deg perf gun and tie into Halliburton Log. Took 2 hrs to get to 1500' and then it started going in hole ok (paraffin?). Ran correlation log and send to town.Told shift up 1'. Shifted log and pulled up to stop depth at 10,382.6' That's CCL/GR to top shot. Spotted and fired gun from 10,405' to 10,410' with 500 psi on tubing. Got good indication of gun firing. Saw no pressure increase in 15 min. POOH. All shots fired. Rig down lubricator and turn well over to field. 03/29/2018-Thursday PTW and JSA. Rig up Pollard EL lubricator and pressure test to 250 psi low and 3,000 psi high. Shut well in. Dump 5 gal diesel down hole. RIH w/2-1/2" x 20' Connex HC, 6 spf, 60 deg phase and tie into OHL. Run correlation log and send to town.Told to shift log up 1'. Shifted log up 1' and log up to stop depth at 10,395.5' (14.5'from CCL/GR to top shot). Fired gun from 10,410' to 10,430' with 1,000 psi on tubing. Saw good indication gun went off. Saw no pressure increase after 15 min. POOH. All shots fired. Rig down lubricator and equipment.Turn well over to field and move to SCU 44B-33. • Swanson River Unit H 0 Well: SCU 41B-04 SCHEMATIC Completion Ran 1/29/15 PTD: 214-177 Hilcorp Alaska,LLC API: 50-133-10109-03 KB-THF: 18.00' GL=173.7'AMSL CASING DETAIL ; 1 l Size Type Wt Grade Conn. ID Top Btm 22' 2 •' L1 61 22" Conductor Surf 22' 13 3/8" Surf.Csg 54.5 J-55 STC 12.615" Surf 3,000' a DV Collar I P1 29 N-80 BTC 6.184" Surf 304' 1 2,002' 26 N-80 BTC 6.276" 304' 1,235' el 423 N-80 BTC 6.366" 1,235' 4,229' 7" Production Casing 26 N-80 BTC 6.276" 4,229' 4,527' 13-3/8"G A , 29 N-80 LTC 6.184" 4,527 6,489' 26 N-80 LTC 6.276" 6,489' 9,055' 1 4-1/2" Production Liner 12.6 L-80 DWC/C-HT 3.958" 8,842' 10,998' i 31 TUBING 3-1/2" Production Tubing 9.3 L-80 8RD 2.992 0' 8,836' 7 N 4 JEWELRY DETAIL No. Depth ID OD Item w,t #' 1 18' 2.950" - Tubing Hanger,3-1/2"8RD Box x 3-1/2"8RD Box y DV Collar 2 19' 2.992" 3.500" Pups,3-1/2"8RD -= 6,944' 3 3,994' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#4(Dummy) V, A 4 4,893' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#3(Live Valve) 0t' 5 8,625' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#2(Dummy) 6 8,732' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#1(Orifice Valve) 5 I 61.1 7 8,784' 2.992" 5.250" Chemical Injection Mandrel(Live Valve,3,000 psi) A 8 8,807' 3.000" 5.875" Hydraulic Packer 6 ; 9 8,827' 2.813" 4.500" X-Nipple ' 10 8,836' 2.992" 4.500" WL Entry Guide 7 11 10,854' - - Fish-Gaslift Dummy Valve(Lost 2/04/15) 12 10,854' Fish-Gaslift Dummy Valve(Lost 2/01/15) 1411 I 8 Short RA Marker Joints ' * @ 10,346'40,359'MD @ 10,547'-10,561'MD 9 + 8;10,680'-10,694'MD '-Ci I '10772-10,786'MD i. 10i PERFORATION DETAIL 2- e L Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date H-1 10,405' 10,410' 10,326' 10,330' 5 6 2-1/2"Connex 03/27/18 �i,.---- CBL(2/03/15) r. H-1/H-2 10,410' 10,430' 10,330' 10,346' 20 6 2-1/2"Connex 03/29/18 9,784' H-2 ±10,425' ±10,445' ±10,150' ±10,167' ±20 6 ** Proposed 11 H-3 ±10,454' ±10,466' ±10,174' ±10,184' ±12 6 ** Proposed RAMrkJt 4 4 H-5 ±10,489' ±10,564' ±10,203' ±10,265' ±75 6 ** Proposed p!'.4_ > H-1 H-6 ±10,579' ±10,587' ±10,279' ±10,286' ±8 6 ** Proposed ','i —+ H-2 H-7 10,607' 10,642' 10,494' 10,523' 35 6 2-1/2"Connex 06/02/15 t47 .1 H-3 H-7L ±10,694' ±10,705' ±10,376' ±10,385' ±11 6 ** Proposed VI H-5 H-9 10,725' 10,777' 10,593' 10,637' 52 6 2-1/2"Connex 02/04/15 RA Mrk Jt -A H-6 1 i;i4 **PLEASE NOTE: Remaining perfs from 10-403 Sundry 318-108(appear as"purple"on the schematic PERFORATION DETAIL)may be shot after drilling of new gas infection well(per telecon G Schwartz/T Kramer 04-26-18). 0H-7 RA nlrkJt '- GLV Port Temp @ I # Size Depth TCF PSC PSO PTRO Description H-7L 16 115 0.883 1183 1309 1500 IPOR-1/IPOC-1/PPOR-1 RA MrkJt I H-9 III 20 157 0.811 ORIFICE-1 11 , 12 ', Tag PBTD @ 10,854'SLM WELL DATA ,+ 2.50"Gauge Ring 6"Hole 2/01/15 PTD:214-177 4-1/2" API: 50-133-10109-03 TD=11,003'MD-10,829'TVD Max Deviation 34°@ 10,402' Lease: FEDA-028997 PBTD=10,870'MD-10,716'TVD Max Dogleg 10.8°/100'@ 9,068' Spud Date:12/24/2014 Tree cxn: 3.5"Bowen Downhole Revised:2/04/15 Updated by DMA 04/27/18 Lift Threads: 3-1/2"8RD L OF Tit, • ywP��\I�j, s THE STAT Alaska Oil and Gas N�►'i� �, Te® c TA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 O .1433 Main: 907.279.7542 4LAS� www.aogcc.alaska.gov Chad Helgeson Operations Manager -' Hilcorp Alaska, LLC 3 800 Centerpoint Drive, Suite 1400 Anchorage,AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 41B-04 Permit to Drill Number: 214-177 Sundry Number: 318-108 Dear Mr. Helgeson: 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, Hollis S. French Chair DATED this-1 day of March, 2018. • 0 • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION �R 13Z18 /�� APPLICATION FOR SUNDRY APPROVALS c3 / 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown 0 Suspend ❑ Perforate Q` Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill 0 Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 14.Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development ❑✓ • 214-177 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-133-10109-03-4--C2 7.If perforating: 8.Well Name and Number: f . What Regulation or Conservation Order governs well spacing in this pool? CO 123B • Soldotna Creek Unit(SCU)41 B-04 . Will planned perforations require a spacing exception? Yes ❑ No 0 9. Property Designation(Lease Number): 10. Field/Pool(s): A028997^ Swanson River Field/Hemlock Oil 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): 11,003' • 10,829' ' 10,870' 10,716' 2,064 psi N/A 10,854'(fish) Casing Length Size MD TVD Burst Collapse Structural Conductor 22' 22" 22' 22' Surface 3,000' 13-3/8" 3,000' 3,000' 2,730 psi 1,130 psi Intermediate Production 9,055' 7" 9,055' 9,055' 6 340 si 3 830 psi P Liner 2,154' 4-1/2" 10,998' 10,826' 8,430 psi 7,500 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2" 9.3#/L-80 8,836 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Hydraulic Pkr; N/A 8,807'MD/8,807'TVD; N/A 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 2 • Service ❑ 14. Estimated Date for 15.Well Status after proposed work: 3/28/2018 Commencing Operations: OIL Q • WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG 0 GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown 0 Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson 777-8405 Contact Name: Taylor Nasse Authorized Title: Operations Manager Contact Email: tnasse( ihilcorp.com aa Contact Phone: 777-8354 Authorized Signature: t����f�,.....— Date: 3/17/I COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: - ICI Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes 0 No ❑ RBDM�AR 2 1 2018 Spacing Exception Required? Yes ❑ No d Subsequent Form Required: /®-- APPROVED BY l Approved by: 1044111111..CA____ COMMISSIONER THE COMMISSION Date: 1 Z.r it ej k0 ._ 3-2-C"/k #31/,p�<----:-° 3'ft/Es Submit Form and 44/1)j ` Form 10-403 Revised 4/201 Approved applRi 4rl1 lam the date of approval. Attachments in Duplicate rq • • Well Prognosis Well: SCU 416-04 Hilcurp Alaska,LLi Date:3/14/2018 Well Name: SCU 41B-04 API Number: 50-133-10109-03 Current Status: Gas Lifted Producer Leg: N/A Estimated Start Date: March 28th, 2018 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-177 First Call Engineer: Taylor Nasse (907) 777-8354 (0) (907) 903-0341 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824(M) Current Bottom Hole Pressure: —2,859 psi @ 10,700' TVD (Based on P/T Survery on 2/5/15) Maximum Expected BHP: —2,859 psi @ 10,700' TVD (Based on P/T Survery on 2/5/15) Max. Allowable Surface Pressure: —2,064 psi (Based on P/T Survery on 2/5/15) Brief Well Summary This well was originally drilled and completed with the Saxon#169 rig in February 2015 in the H-7 Sand. In June 2015 the H-5 was added. The purpose of this work/sundry is to add additional perforations in the H-1, H-2, H-3, H-5, H-6, and H-7L. ' The proposed perforations are in the Hemlock Formation in Swanson River Unit and in accordance with Conservation Order CO123B, there are no restrictions to well spacing within the Hemlock Oil Pool between wells and this well is more than 500 feet of the external property line. E-line Procedure: 1. MIRU E-line, PT Lubricator to 3,000 psi Hi 250 Low. a. Tree connection is 3.5" Bowen. 2. RU HC wireline guns. 3. SI and bleed tubing pressure down, as directed by Reservoir Engineer. 4. RIH and perforate the following interval: Zone Sands Top (MD) Btm (MD) FT Hemlock H-1 10,400' 10,425' 25 Hemlock H-2 10,425' 10,445' 20 Hemlock H-3 10,454' 10,466' 12 Hemlock H-5 10,489' 10,564' 75 Hemlock H-6 10,579' 10,587' 8 Hemlock H-7L 10,694' 10,705' 11 a. Proposed perfs shown on the proposed schematic in red font. b. Final Perfs tie-in sheet will be provided in the field for exact perf interval. c. Correlate using proposed Gamma/CCL. d. Record tubing pressures before and after each perforating run. 5. POOH. RD E-line. 6. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic i * Swanson River Unit • Well: SCU 418-04 SCHEMATIC Completion Ran 1/29/15 PTD: 214-177 Hilcorp Alaska,LLC API: 50-133-10109-03 KB-THF: 18.00' GL=173.7'AMSL CASING DETAIL 1lSize Type Wt Grade Conn. ID Top Btm 22"� 2 ,i L� 22" Conductor - - - Surf 22' 13-3/8" Surf.Csg 54.5 J-55 STC 12.615" Surf 3,000' DV Collar 29 N-80 BTC 6.184" Surf 304' 2,002' 26 N-80 BTC 6.276" 304' 1,235' ' t,..- 7" Production Casing 23 N-80 BTC 6.366" 1,235' 4,229' % 26 N-80 BTC 6.276" 4,229' 4,527' 13-3/8" i /i 29 N-80 LTC 6.184" 4,527' 6,489' 7J 26 N-80 LTC 6.276" 6,489' 9,055' 4-1/2" Production Liner 12.6 L-80 DWC/C-HT 3.958" 8,842' 10,998' 3 TUBING �j 3-1/2" Production Tubing 9.3 L-80 8RD 2.992 0' 8,836' l ,a 4, 4 7 JEWELRY DETAIL k No. Depth ID OD Item 1 �_ 1 18' 2.950" - Tubing Hanger,3-1/2"8RD Box x 3-1/2"8RD Box 0 d. DV Collar 2 19' 2,992" 3.500" Pups,3-1/2"8RD ' 6,944' 3 3,994' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#4(Dummy) 54 LA s 4 4,893' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#3(Live Valve) 144 5 8,625' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#2(Dummy) 6 8,732' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#1(Orifice Valve) 5 i 7 8,784' 2.992" 5.250" Chemical Injection Mandrel(Live Valve,3,000 psi) 8 8,807' 3.000" 5.875" Hydraulic Packer 6 9 8,827' 2.813" 4.500" X-Nipple 10 8,836' 2.992" 4.500" WL Entry Guide ye 7 11 10,854' - - Fish—Gaslift Dummy Valve(Lost 2/04/15) 0 II12 10,854' - - Fish—Gaslift Dummy Valve(Lost 2/01/15) 01 14 I I I 8 Short RA Marker Joints ID A @ 10,346'-10,359'MD 9 @ 10,547'-10,561'MD IS 10 @ 10,680'-10,694'MD A @ 10,772'-10,786'MD 7,. PERFORATIONS CBL(2/03/11) Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date 9,784' H-5 10,607' 10,642' 10,493' 10,523' 35 6 2-1/2"Connex 06/02/15 H-7 10,725' 10,777' 10,593' 10,637' 52 6 2-1/2"ConneX 02/04/15 RA Mrk Jt 4 „„ 4,4 5 7 rt GLV Port Temp @ q # Size Depth TCF PSC PSO PTRO Description RA Mrk J[ it 2 16 11151 0.883 1183 1309 1500 IPOR-1/IPOC-1/PPOR-1 1 20 0.811 ORIFICE-1 vi 0 ":0.4 ”" 11-5 V RA Mrk Jt Ini ea: k Y f .,. 11-7 RA Mrk Jt i WELL DATA 11 "•-' PTD:214-177 Tag PBTD @ 10,854SLM i•i 12 eeW 1; 2.50"Gauge Ring API: 50-133-10109-03 r £ 2/01/15 Lease: FEDA-028997 I, 6"Hole Spud Date:12/24/2014 TD=11,003'MD—10,829'TVD Max Deviation 34°@ 10,402' Tree cxn: 3.5"Bowen PBTD=10,870'MD—10,716'TVD Max Dogleg 10.8°/100'@ 9,068' Lift Threads: 3-1/2"8RD Downhole Revised:2/04/15 Updated by DMA 06/30/15 410• • Swanson River Unit Well: U PROPOSED Completion SCRan41B-04 1/29/15 PTD: 214-177 Hilcorp Alaska,LLC SCHEMATIC API: 50-133-10109-03 KB-THF: 18.00' GL= 173.7'AMSL CASING DETAIL i l Size Type Wt Grade Conn. ID Top Btm 22" 2 �, L1 22" Conductor Surf 22' "° 13-3/8" Surf.Csg 54.5 1-55 STC 12.615" Surf 3,000' DV Collar 29 N-80 BTC 6.184" Surf 304' 2,002' 26 N-80 BTC 6.276" 304' 1,235' e 0 7" Production Casing 23 N-80 BTC 6.366" 1,235' 4,229' 26 N-80 BTC 6.276" 4,229' 4,527' 13-3/8' ; 29 N-80 LTC 6.184" 4,527' 6,489' I,. 26 N-80 LTC 6.276" 6,489' 9,055' ," 4 4-1/2" Production Liner 12.6 L-80 DWC/C-HT 3.958" 8,842' 10,998' r 3 i TUBING ,, 3-1/2" Production Tubing 9.3 L-80 8RD 2.992 0' 8,836' 4 I JEWELRY DETAIL ~ No. Depth ID OD Item kr 1 18' 2.950" - Tubing Hanger,3-1/2"8RD Box x 3-1/2"8RD Box DV Collar 2 19' 2.992" 3.500" Pups,3-1/2"8RD . 6,944' 3 3,994' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#4(Dummy) A 4 4,893' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#3(Live Valve) 5 8,625' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#2(Dummy) 6 8,732' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#1(Orifice Valve) i 7 8,784' 2.992" 5.250" Chemical Injection Mandrel(Live Valve,3,000 psi) 8 8,807' 3.000" 5.875" Hydraulic Packer ' 6 i 9 8,827' 2.813" 4.500" X-Nipple :rar. 10 8,836' 2.992" 4.500" WL Entry Guide 11 10,854' Fish-Gaslift Dummy Valve(Lost 2/04/15) 1 12 10,854' - - Fish-Gaslift Dummy Valve(Lost 2/01/15) 8 = ,A; Short RA Marker Joints ' @ 10,346'-10,359'MD aa` @ 10,547'-10,561'MD N. 9 a Mp, @ 10,680'-10,694'MD 10 .. 1100"+ @ 10,772'-10,786'MD PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date H-1 10,400' 10,425' 10,129' x,150' 25 6 TBD CBL(2/03/15) H-2 10,425' 10,445' 10,150' 10,167' 20 6 TBD 9,784' ►'' # H-3 10,454' 10,466' 10,174' 10,184' 12 6 TBD RA Mrk Jtq H-5 10,489' 10,564' 10,203' 10,265' 75 6 TBD H 1 H-6 10,579' 10,587' 10,279' 10,286' 8 6 TBD H-2 H-5 10,607' 10,642' 10,493' 10,523' 35 6 2-1/2"Connex 06/02/15 `' H-7L 10,694' 10,705' 10,376' 10,385' 11 6 TBD s H5 H-7 10,725' 10,777' 10,593' 10,637' 52 6 2-1/2"ConneX 02/04/15 RA Mrk Jt ill ;: o H-6 CLv Port Temp © it 5 # Size Depth TCF PSC PSO PTRO Description 2 16 115 0.883 1183 1309 1500 IPOR-1/IPOC-1/PPOR-1 RA Mrk Jt '` 1 20 157 0.811 ORIFICE-1 .:f H-7I. WELL DATA RA Mrk Jt H-7 C 11 x* Tag PBTD @ 10,854'SLM PTD:214-177 ` 12 s 2.50"Gauge Ring API: 50-133-10109-03 P,, 3 2/01/15 Lease: FEDA-028997 4-1/2„' s -• 0 6 "Hole Spud Date:12/24/2014 TD=11,003'MD-10,829'ND Max Deviation 34°@ 10,402' Tree cxn: 3.5"Bowen PBTD=10,870'MD-10,716'TVD Max Dogleg 10.8°/100'@ 9,068' Lift Threads: 3-1/2"8RD Downhole Revised:2/04/15 Updated by TWN 03/14/18 Seth Nolan Hilcorp Alaska, LLC +e 6 7 6 8 GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8308 Irh„rp 11:140_LI I Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATA LOGGED 2/41/201( M.K. BENDER DATE 01/20/16 RECEIVED To: Alaska Oil & Gas Conservation Commission FEB 0 2 2f16 Makana Bender Natural Resource Technician II AOGCC 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL SCU 41B-04 Elog prints and digital data scope J U L 2 8 2016 016 Prints: SCMT-GR-CCL CD1: Elog digital data RST 2/6/2015 1:00 PM File folder SCMT 2/6/20151:00 PM 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: �a�d nti 6,,,ufatDate: STATE OF ALASKA RECEIVED - Ai_ _KA OIL AND GAS CONSERVATION COM.„..SSION JUL 0 1 20,r 13 REPORT OF SUNDRY WELL OPERATIONS 0G G 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing H �perat s�huwown U Performed: Suspend ❑ Perforate ❑✓ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool El Repair Well ❑ Re-enter Susp Well❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development Q Exploratory ❑ 214-177 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-133-10109-03 7.Property Designation(Lease Number): 8.Well Name and Number: A028997 Soldotna Creek Unit(SCU)41 B-04 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Swanson River Field/Hemlock Oil 11.Present Well Condition Summary: Total Depth measured 11,003 feet Plugs measured N/A feet true vertical 10,829 feet Junk measured 10,854'(fish) feet Effective Depth measured 10,870 feet Packer measured 8,807 feet true vertical 10,716 feet true vertical 8,807 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 22' 22" 22' 22' Surface 3,000' 13-3/8" 3,000' 3,000' 2,730 psi 1,130 psi Intermediate Production 9,055' 7" 9,055' 9,055' 6,340 psi 3,830 psi Liner 2,154' 4-1/2" 10,998' 10,826' 8,430 psi 7,500 psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic SCANNED JUL 0 9 Z Q 1 Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3#/L-80 8,836'MD 8,836'ND Packers and SSSV(type,measured and true vertical depth) Hydraulic Pkr;N/A 8,807'MD 8,807'ND N/A;N/A 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-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 169 718 0 475 225 Subsequent to operation: 441 1120 0 510 150 14.Attachments(required per 20 AAC 25 070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑., Exploratory❑ Development❑✓ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ El 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: 315-310 Contact Joe Kaiser Email jkaiser(c hilcoro.com Printed Name Joe Kaiser Title Operations Engineer Signature 11` Phone 907-777-8393 Date �' RBDMS JUL - 2015 Form 10-404 Revised 5/2015 7G' S Submit Original Only • in" Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 41B-04 50-133-10109-03 214-177 6/1/15 6/2/15 Daily Operations: 06/01/2015- Monday PTW and JSA. Mobe to location and spot equipment. Rig up what we can while waiting on ASRC crane. SLB fan on the truck went out so they worked and fixed that. Was rigging up and radiator on ASRC crane developed a leak. Callled out mechanic and was told stop leak wouldn't fix.They could get another crane in the morning. Rigged for standby. 06/02/2015-Tuesday PTW and JSA. Mobe to location. Spot crane and rig back up lubricator. Pressure test lubricator to 250 psi low and 3,000 psi high. Arm gun. RIH w/2" x 20' HC, 6 spf, 60 deg phase perf gun and tie into SLB RST log. Ran correlation and send to town. Was told to move log down hole 2.5' per open hole log. Make correction and send back to town. Get ok to perf from 10,642' to 10,622'. Fired gun with 160 psi on well. No psi increase POOH.. Arm gun. RIH w/2"x15' HC, 6 spf, 60 deg phase perf gun and tie into SLB correlation log revised. Ran corrleation log and send to town. Get ok to perf from 10,622' to 10,607'. Reservoir engineer had me shut well in right before we shot. Shut well in with 250 psi. Spotted shot and fired gun. POOH. Rig down lubricator and turn well back over to field. • n . Swanson River Unit Well: SCU 41B-04 SCHEMATIC Completion Ran 1/29/15 PTD: 214-177 Ililcorp Alaska,LLC API: 50-133-10109-03 KB-THF: 18.00' GL= 173.7'AMSL CASING DETAIL 1 L Size Type Wt Grade Conn. ID Top Btm 22' 2 22" Conductor - - - Surf 22' 13-3/8" Surf.Csg 54.5 J-55 STC 12.615" Surf 3,000' • DV Collar 29 N-80 BTC 6.184" Surf 304' 2,002' 26 N-80 BTC 6.276" 304' 1,235' 7" Production Casing 23 N-80 BTC 6.366" 1,235' 4,229' 26 N-80 BTC 6.276" 4,229' 4,527' 13-3/8" 29 N-80 LTC 6.184" 4,527' 6,489' 26 N-80 LTC 6.276" 6,489' 9,055' 4-1/2" Production Liner 12.6 L-80 DWC/C-HT 3.958" 8,842' 10,998' 31 - TUBING II 3-1/2" Production Tubing 9.3 L-80 8RD 2.992 0' 8,836' 4F ill JEWELRY DETAIL No. Depth ID OD Item 1 18' 2.950" - Tubing Hanger,3-1/2"8RD Box x 3-1/2"8RD Box ' 1 DV Collar 2 19' 2.992" 3.500" Pups,3-1/2"8RD 6,944' 3 3,994' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#4(Dummy) 4 4,893' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#3(Live Valve) 5 8,625' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#2(Dummy) 6 8,732' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#1(Orifice Valve) $ 7 8,784' 2.992" 5.250" Chemical Injection Mandrel(Live Valve,3,000 psi) I8 8,807' 3.000" 5.875" Hydraulic Packer 6 hl 9 8,827' 2.813" 4.500" X-Nipple 10 8,836' 2.992" 4.500" WL Entry Guide +• 7 r D 11 10,854' - - Fish—Gaslift Dummy Valve(Lost 2/04/15) Ll. 12 10,854' - - Fish—Gaslift Dummy Valve(Lost 2/01/15) 3F 8 A M Short RA Marker Joints q @ 10,346'-10,359'MD @ 10,54T-10,561'MD 10 @ 10,680'-10,694'MD • @ 10,772'-10,786'MD 7 it PERFORATIONS CBI,(2iO3i15); Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date 9,784' • • ►, H-5 10,607' 10,642' 10,493' 10,523' 35 6 2-1/2"Connex 06/02/15 r �°i� H-7 10,725' 10,777' 10,593' 10,637' 52 6 2-1/2"ConneX 02/04/15 RAMrkJt ■ ti GLV Port Temp @ # Size Depth TCF PSC PSO PTRO Description • RA Mrk Jt in rz, 2' 16 115 0.883 1183 1309 1500 IPOR-1/IPOC-1/PPOR-1 1 20 157 0.811 ORIFICE-1 • ::-'"--11-5 • --it.— RA Mrk Jt a I .,l_ 11-7 RA MrkJt i WELL DATA 11 , , PTD:214-177 Tag PBTD @ 10,854SLM ,; 129' ,,, 2.50"Gauge Ring API: 50-133-10109-03 ^ ; y C. 2/01/15 Lease: FEDA-028997 4-1/2"''id:+.. .. y 6"Hole Spud Date:12/24/2014 TD=11,003'MD—10,829'ND Max Deviation 34°@ 10,402' Tree cxn: 3.5"Bowen PBTD=10,870'MD—10,716'ND Max Dogleg 10.8°/100'@ 9,068' Lift Threads: 3-1/2"8RD Downhole Revised: 2/04/15 Updated by DMA 06/30/15 1 ti.+ QF Tye • �w,w\�����j��sv THE STATE Alaska Oil and Gas i, , �14 OfA L A S KA Conservation Commission 71-_-_--4:i:,-- 333 West Seventh Avenue ;: GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main 907 279 1433 OA, Fax: 907.276 7542 www.aogcc.alaska gov IS Joe Kaiser SCO4t phi O Operations Engineer � �J 7 Hilcorp Alaska, LLC Cif, t "` , / 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 41B-04 Sundry Number: 315-310 Dear Mr. Kaiser: 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, --'1141j°, Cathy P. Foerster Chair DATED this 2-7t;of May, 2015 Encl. RECEIVED STATE OF ALASKA MAY 2 0 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION O0 S 5`2-7715 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1.Type of Request: Abandon❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend❑ Perforate E. Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other. ❑ 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill l Number Exploratory ❑ Development ❑' • 214-177 - 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number Anchorage,Alaska 99503 50-133-10109-03 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 123B Soldotna Creek Unit(SCU)41 B-04 • Will planned perforations require a spacing exception? Yes ❑ No ❑., 9.Property Designation(Lease Number): 10.Field/Pool(s): A028997 ' Swanson River Field/Hemlock Oil ' 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): 11,003' ' _ 10,829' ' 10,870' ` 10,716' • N/A 10,854'(fish) Casing Length Size MD TVD Burst Collapse Structural Conductor 22' 22" 22' 22' Surface 3,000' 13-3/8" 3,000' 3,000' 2,730 psi 1,130 psi Intermediate Production 9,055' 7" 9,055' 9,055' 6,340 psi 3,830 psi - Liner 2,154' 4-1/2" 10,998' 10,826' 8,430 psi 7,500 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2" 9.3*/L-80 8,836 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Hydraulic Pkr;N/A 8,807'MD/8,807'ND;N/A 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑r Service ❑ 14.Estimated Date for 15.Well Status after proposed work: CommencingOperations: 6/3/15 OIL WINJ WDSPL P ❑ ❑ ❑ Suspended 0 16.Verbal Approval: Date: GAS ❑ 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 Joe Kaiser Email jkaiser@hilcorp.com Printed Name J _�yy.er Title Operations Engineer Signature - f Phone 907-777-8393 Date S/ZC'/;� COMMISSION USE ONLY Condition-of approval: Notify Commission so that a representative may witness Sundry Number: -SlO Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ Nodi Subsequent Form Required: /O — `boy APPROVED BY Approved by: a44,2 COMMISSIONER THE COMMISSION Date-S---2--.2--/- Submit ri". R I e N A Submn Forth and Form 10-403 Revised 5/2015 ;i)voy t Is/HyYli fOrDMStI, f OmMAYdate of approval. 2 Attachments in Duplicate S.2ti8 1015/f .1///✓- sb s 7_/. /S Well Prognosis Well: SCU 41B-04 lliIcorp Alaska,LL Date:5/20/2015 Well Name: SCU 41B-04 API Number: 50-133-10109-03 Current Status: New Sidetrack Leg: N/A Estimated Start Date: June 3rd, 2015 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-177 First Call Engineer: Joe Kaiser (907)777-8393(0) (907)952-8897 (M) Second Call Engineer: Chad Helgeson (907)777-8405 (0) (907) 229-4824(M) Current Bottom Hole Pressure: —2,859 psi @ 10,637' ND (Based on P/T Survery on 2/5/15) Maximum Expected BHP: —2,859 psi @ 10,637' ND (Based on P/T Survery on 2/5/15) Max. Allowable Surface Pressure: —2,064 psi (Based on P/T Survery on 2/5/15) Brief Well Summary This well was drilled and completed with the Saxon#169 rig. In February 2015,the H-7 Sand was perforated. • The purpose of this work/sundry is to add additional perforations in the H-5 Sand. The proposed perforations are in the Hemlock Formation in Swanson River Unit and in accordance with Conservation Order CO123B,there are no restrictions to well spacing within the Hemlock Oil Pool between wells and this well is more than 500 feet of the external property line. E-line Procedure: 1. MIRU E-line, PT Lubricator to 3,000 psi Hi 250 Low. a. Tree connection is 3.5" Bowen. 2. RU 2.5" HC wireline guns(6 spf shot density). 3. SI and bleed tubing pressure down, as directed by Reservoir Engineer. 4. RIH and perforate the following interval: Zone Sands Top (MD) Btm (MD) FT SPF Hemlock H-5 10,607' 10,642' 35 6 a. Proposed perfs shown on the proposed schematic in red font. b. Final Perfs tie-in sheet will be provided in the field for exact perf interval. c. Correlate using proposed Gamma/CCL d. Record tubing pressures before and after each perforating run. 5. POOH. RD E-line. 6. Turn well over to production Attachments: 1. Actual Schematic 2. Proposed Schematic , ill Swanson River Unit Well: SCU 4113-04 ACTUAL SCHEMATIC Completion Ran 1/29/15 PTD: 214-177 Ililcorp Alaska,LLC API: 50-133-10109-03 KB-THF: 18.00' GL=173.7'AMSL CASING DETAIL J t � �, [ Size Type Wt Grade Conn. ID Top Btm zz'Q 2 IMI22" Conductor - Surf 22' 13-3/8" Surf.Csg 54.5 1-55 STC 12.615" Surf 3,000' ' Z DV Collar 29 N-80 BTC 6.184" Surf 304' 1 2,002' 26 N-80 BTC 6.276" 304' 1,235' 7" Production Casing 23 N-80 BTC 6.366" 1,235' 4,229' • 26 N-80 _ BTC 6.276" 4,229' 4,527' 13-3/8" 29 N-80 LTC 6.184" 4,527' 6,489' 26 N-80 LTC 6.276" 6,489' 9,055' I. 4-1/2" Production Liner 12.6 L-80 DWC/C-HT 3.958" 8,842' 10,998' 3 % H • TUBING 3-1/2" Production Tubing 9.3 L-80 8RD 2.992 0' 8,836' • ' 4 F ' V JEWELRY DETAIL No. Depth ID OD Item ," 1 18' 2.950" - Tubing Hanger,3-1/2"8RD Box x 3-1/2"8RD Box ' ' II DV Collar 2 19' 2.992" 3.500" Pups,3-1/2"8RD 6,944' 4 3 3,994' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#4(Dummy) 4 4,893' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#3(Live Valve) t, 5 8,625' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#2(Dummy) II 6 8,732' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#1(Orifice Valve) 5 1B i 7 8,784' 2.992" 5.250" Chemical Injection Mandrel(Live Valve,3,000 psi) 8 8,807' 3.000" 5.875" Hydraulic Packer 6 ' i ik 9 8,827' 2.813" 4.500" X-Nipple *4 10 8,836' 2.992" 4.500" WL Entry Guide 11 10,854' - - Fish—Gaslift Dummy Valve(Lost 2/04/15) 12 10,854' - - Fish—Gaslift Dummy Valve(Lost 2/01/15) 8 =_ - Short RA Marker Joints In ® 10,346'-10,359'MD • 9 = @ 10,54T-10,561'MD @ 10,680'-10,694'MD 10 @ 10,772'-10,786'MD 7" i PERFORATIONS CBL(2/03/15)- Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date 9,784' w:. , H-7 10,725' 10,777' 10,593' 10,637' 52 6 2-1/2"ConneX 2/04/15 • RA Mrk Jt1114 tGLV Port Temp :V # Size Depth TCF PSC PSO PTRO Description RA Mrk Jt 2 16 115 0.883 1183 1309 1500 IPOR-1/IPOC-1/PPOR-1 1 20 157 0.811 ORIFICE-1 6` RA Mrk Jt ,--1_ RA Mrk Jt 11-7 WELL DATA y; iE 11 Tag PBTD @ 10,854'SLM PTD:214-177 1 12 ,V, 2.50"Gauge Ring API: 50433-10109-03 .44 1 2/01/15 Lease: FEDA-028997 4-1/2" 44 ' ' ; 6"Hole Spud Date:12/24/2014 TD=11,003'MD—10,829'TVD Max Deviation 34°@ 10,402' Tree cxn: 3.5"Bowen PBTD=10,870'MD—10,716'ND Max Dogleg 10.87100'@ 9,068' Lift Threads: 3-1/2"8RD Downhole Revised:2/04/15 Updated by STP 2/06/15 II Swanson River Unit Well: SCU 41B-04 PROPOSED SCHEMATIC Completion Ran 1/29/15 PTD: 214-177 Hilcorp Alaska,LLC API: 50-133-10109-03 KB-THF: 18.00' GL= 173.7'AMSL CASING DETAIL delJ t 2 Size Type Wt Grade Conn. ID Top Btm 22" Conductor - - - Surf 22' Pr 13-3/8" Surf.Csg 54.5 J-55 STC . 12.615" Surf 3,000' I DV Collar 29 N-80 BTC 6.184" Surf 304' 2,002' 26 N-80 BTC 6.276" 304' 1,235' !i 7" Production Casing 23 N-80 BTC 6.366" 1,235' 4,229' 26 N-80 BTC 6.276" 4,229' 4,527' 13-3/8" 29 N-80 LTC 6.184" 4,527' 6,489' P. 26 N-80 LTC 6.276" 6,489' 9,055' 4-1/2" Production Liner 12.6 L-80 DWC/C-HT 3.958" 8,842' 10,998' 3 TUBING 3-1/2" Production Tubing 9.3 L-80 8RD 2.992 0' 8,836' 4 JEWELRY DETAIL No. Depth ID OD Item ji 1 18' 2.950" - Tubing Hanger,3-1/2"8RD Box x 3-1/2"8RD Box DV Collar 2 19' 2.992" 3.500" Pups,3-1/2"8RD ♦• 6,944' 3 3,994' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#4(Dummy) ' 4 _ 4,893' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#3(Live Valve) �� 5 _ 8,625' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#2(Dummy) 4 6 8,732' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#1(Orifice Valve) a 5r1 rs i 7 8,784' 2.992" 5.250" Chemical Injection Mandrel(Live Valve,3,000 psi) 8 8,807' 3.000" 5.875" Hydraulic Packer 6 1 b 9 8,827' 2.813" 4.500" X-Nipple ,..,"1 10 8,836' 2.992" 4.500" WL Entry Guide .• 7 11 10,854' - - Fish—Gaslift Dummy Valve(Lost 2/04/15) 12 10,854' - - Fish—Gaslift Dummy Valve(Lost 2/01/15) • 1I � _ I' ' 8 = ;:.:-= .' Short RA Marker Joints @ 10,346'-10,359'MD 9 X '' @ 10,547'-10,561'MD f @ 10,680'-10,694'MD 10 @ 10,772'-10,786'MD IS PERFORATIONS CBL(2/03/15) Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date 9,784' rli H-5 10,607' 10,642' 10,493' 10523' 35 6 2-1/2"Connex H-7 10,725' 10,777' 10,593' 10,637' 52 6 2-1/2"ConneX 2/04/15 • RA Mrk Jt DI t4 • 1 GLV Port Temp @ # Size Depth TCF PSC PSO PTRO Description i. RA MrkJt E 2 16 115 0.883 1183 1309 1500 IPOR-1/IPOC-1/PPOR-1 1 20 157 0.811 ORIFICE-1 H-5 RA Mrk Jt il .• tr i H-7 RA Mrk Jt WELL DATA l ly, Tag PBTD @ 10,854'SLM PTD:214-177 I2,c ,ft 2.50"Gauge Ring API: 50-133-10109-03 - 4 ;t, 2/01/15 Lease: FEDA-028997 Vi 4 i/2"' 4iia 6"Hole Spud Date:12/24/2014 4-1/2"A TD=11,003'MD—10,829'ND Max Deviation 34°@ 10,402' Tree cxn: 3.5"Bowen PBTD=10,870'MD-10,716'ND Max Dogleg 10.8°/100'@ 9,068' Lift Threads: 3-1/2"8RD Downhole Revised:2/04/15 Updated by JEK 5/19/15 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. <a] 4_- 4 77 Well History File Identifier Organizing(done) ❑ Two-sided ❑ Rescan Needed RESCAN: OVERSIZED: NOTES: --! r Items: ❑ Maps: rayscale Items: ogs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: N io _ BY: Date: � iV 1 _ /s/ Project Proofing p BY: Maria Date: 1 i [a..1 S /s/ Scanning Preparation 3 x 30 = O + 19 = TOTAL PAGES i © q (Count does not include cover sheet) BY: Maria Date: i /s/ 11 Production Scanning Stage 1 Page Count from Scanned File: 1 10 (Count does include cover s t) Page Count Matches Number in Scanning Preparation: ES NO BY: 412, Date: (0 l 131 15 /s/ iv tr Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: (01-1 Digital version appended by: Meredithf\46Michal Date: CPI I SI y 5. /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: 1 7 4 Scanning is complete at this point unless rescanning is required. 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Z I ti M• 0 c n in 5141 F Z F. Q J wry O CO o 0) co co V c D N J �i J y 7 a cncc 1 cc a. Q re W v Z Q . N Ja CL co � � o Oo ° a N E U � o J Q m CO a 11' . v r H Z C o G m N W Q N p Z N CO Q co J Q Ocn o II ti Qo a o 0 £ o co Z d rn • N CO 0 I.... > m H v 3 ✓ 41 N d d' D • M o _ o.2C U : 0. E 0 c oQ a 2 0 j114-1 -1-7- IIlith Nolan Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive �� Anchorage, AK 99503 Tele: 907 777-8308 li.l,•��p tI:k.k:..IT( Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATE 04/23/2015 To: Alaska Oil & Gas Conservation Commission Meredith Guhl Petroleum Geology Assistant 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL SCU 41B-04 3 boxes: Dry Cuttings Transmitted herewith are cuttings from SCU 41 B-04 WELL SAMPLE INTERVAL SCU 41B-04 9090'-10290 SCU 41B-04 10290'—11000' SCU 41 B-04 9210'—9990' Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received y:4777(.., Date: RECEIVED c - APR 2 4 2015 AOGCC RECEIV Hilcorp Alaska, LLC Post Office Box 244027 MAR 0 4 2015 Anchorage,AK 99524-4027 ee r(�r{^_ 3800 Centerpoint Drive �"lO�.r1 V� Suite 1400 Anchorage,AK 99503 Phone: 907/777.8300 March 3, 2015 Fax: 907/777.8301 Alaska Oil and Gas Conservation Commission 333 W. 7t1 Ave., Suite 100 Anchorage, Alaska 99501 Re: SCU 41B-04 Form 10-407 PTD: 214-177 API: 50-133-10109-03-00 Dear Commissioner: Please find the enclosed Well Completion Form 10-407 for SCU 41B-04. Please do not hesitate to contact me should you have any questions or need additional information. Sincerely, HILCORP ALASKA, LLC 1' Cody D. ger Drilling Technician (907)777-8389 cdinger@hilcorp.com 1 of 1 STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMM" ON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a.Well Status: Oil E • Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ lb.Well Class: 20AAC 25.105 20kAC 25.110 Development 11 • Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL❑ No.of Completions: _ 1 • Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp. usp.,or 12.Permit to Drill Number: Hilcorp Alaska, LLC Aban .: 02/4/2015 214-177 • 3.Address: 6. Date Spudded: 13.API Number: 3800 Centerpoint Drive STE 1400 Anchorage,AK 99503 •12/24/2014 50-133-10109-03-00 4a. Location of Well(Governmental Section): 7. Date TD Reached: 14.Well Name and Number: Surface: 961' FNL, 1127'FEL,Sec 4,T7N, R9W, SM,AK " •1/22/2015 SCU 41B-04 • Top of Productive Horizon: 8. KB(ft above MSL): 192.3 Ft. 15.Field/Pool(s): 584'FNL, 1047'FEL,Sec 4,T7N, R9W,SM,AK GL(ft above MSL): 173.7 Ft . Swanson River Field Total Depth: 9. Plug Back Depth(MD+TVD): Hemlock Oil Pool- 261'FNL, 1026'FEL,Sec 4,T7N, R9W, SM,AK - 10,870'MD/10,716'TVD • 4b. Location of Well(State Base Plane Coordinates, NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x- 346506.3 • y- 2460223.8 • Zone- 4 411,003'MD/10,829'TVD • A028997 TPI: 10398 x- 346557.9 y- 2460534.4 Zone- 4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 346600.78 y- 2460915.25 Zone- 4 N/A/N/A N/A 18. Directional Survey: Yes 0 . No ❑ 19.Water Depth, if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) N/A 21. Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drill/Lateral Top Window MD/TVD: ROP-DGR-EWR Z/5"MD SCU 41 B-04/SCU41 B-04 PB1, DGR-EWR Z/5"MD SCU 41 B-04/SCU41 B-04 PB1, .TOW-9,055'MD/9,055'TVD • FML 2"/5"MD, DEL-ML 2"MD,GRL-ML 2"MD 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASINGFr. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 4-1/2" 12.6 L-80 8,842' 10,998' 8,842' 10.825' 6" 92 bbls/15.3 ppg/EZBLOK 24.Open to production or injection? Yes B 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): 3-1/2" 8,836' 8,807'MD/8,807'TVD H-7 Sand Top 10,722'MD, 10,590'TVD 2-4.'41)6 �.ri. Base 10,796'MD, 10,653'TVD 4 26. ACID,FRACTURE,CEMENT SQUEEZE, ETC. Perforations w Xi EC IVEC Was hydraulic fracturing used during completion? Yes ❑ No El10,725'-10,745' r �3- } 0X11 10,745'-10,765' Alit • DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 10,765'-10,777' ?_�J MAR 0 4 2015 2-1/2"ConneX/6 SPF/52'/312 Holes - eOGCC 27. J'� 1�PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift, etc.): 2/4/2015 Flowing Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 2/9/2015 24 Test Period .--0.342 1814 0 64 5,304 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API (corr): Press. 215 540 24-Hour Rate 342 . 1814 l 0 32 28. CORE DATA Conventional Core(s)Acquired? Yes❑ No • Sidewall Cores Acquired? Yes ❑ No ❑✓ If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. Form 10-407 Revised 10/2012 CONTINUED ON REVERSE Submit ori inal only `10-i5" ., - 207,0,--- �� 7.--Z- I� RBDMS< APR - 7 2015 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, Permafrost-Top and submit detailed test information per 20 AAC 25 071. Permafrost-Base Tyonek G2 Sand 10294 10233 Hemlock 10398 10320 Hemlock Bench 2 10447 10361 Hemlock Bench 3 10494 10400 Hemlock Bench 4 10573 10465 Hemlock Bench 5 10599 10487 Hemlock Bench 6 10690 10564 Hemlock Bench 7 10722 10591 Hemlock Bench 8 10801 10657 Hemlock Bench 9 10831 10682 Hemlock Bench 10 10878 10722 Formation at total depth: Hemlock ` 1 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 Cementing Reports. I 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Monty Myers Email. mmyersa,hilcorp.Com Printed Name: Monty Myers Title: Drilling Engineer Signature: --"" Phone: 907-777-8431 Date: 0. a I INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 b: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13. The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 Swanson River Unit Well: SCU 416-04 II ACTUAL SCHEMATIC Completion Ran 1/29/15 PTD: 214-177 Hilcorp Alaska.LLC API: 50-133-10109-03 KB-THF: 18.00' GL= 173.7'AMSL CASING DETAIL I Size Type Wt Grade Conn. ID Top Btm 22-J t." 2 i. y,; 22" Conductor - - - Surf 22' 13-3/8" Surf.Csg 54.5 1-55 N-80 N-80 N-80 STC 12.615" Surf 3,000' DV Collar 29 BTC 6.184" Surf 304' 2,002' 26 BTC 6.276" 304' 1,235' 7" Production Casing 23 BTC 6.366" 1,235' 4,229' '• k 26 N-80 BTC 6.276" 4,229' 4,527' 13-3/8" 29 N-80 LTC 6.184" 4,527' 6,489' 26 N-80 LTC 6.276" 6,489' 9,055' 4-1/2" Production Liner 12.6 L-80 DWC/C-HT 3.958" 8,842' 10,998' 3 E 1 TUBING 3-1/2" Production Tubing 9.3 L-80 8RD 2.992 0' 8,836' 4 %,. JEWELRY DETAIL No. Depth ID OD Item 1 18' 2.950" - Tubing Hanger,3-1/2"8RD Box x 3-1/2"8RD Box ' :'1 DV Collar 2 19' 2.992" 3.500" Pups,3-1/2"8RD r 6'944 3 3,994' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#4(Dummy) 4 4,893' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#3(Live Valve) 5 8,625' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#2(Dummy) 6 8,732' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#1(Orifice Valve) 5 I 7 8,784' 2.992" 5.250" Chemical Injection Mandrel(Live Valve,3,000 psi) 8 8,807' 3.000" 5.875" Hydraulic Packer 6 . i 9 8,827' 2.813" 4.500" X-Nipple I 10 8,836' 2.992" 4.500" WL Entry Guide _, 7 r 11 10,854' - - Fish—Gaslift Dummy Valve(Lost 2/04/15) r I 12 10,854' - - Fish—Gaslift Dummy Valve(Lost 2/01/15) T` yII .. ml. I 'r. i'''' SgAraffrAgrAla 1111 ;' @ 10,346'-10,359'MD 9 E ‘t o @ 10,547'-10,561'MD I• -.1 @ 10,680'-10,694'MD ." 10 W I J @ 10,772'-10,786'MD PERFORATIONS CBL(2/03/15) Zon Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date 9,784' H 10,725' 10,777' 10,593' 10,637' 52 6 2 1/2"ConneX 2/04/15 RA Mrk Jt / (A'O� /' GLV Port Temp @ t # Size Depth TCF PSC PSO PTRO Description RAMrkJtii, ;,; 2 16 115 0.883 1183 1309 1500 IPOR-1/IPOC-1/PPOR-1 1 20 157 0.811 ORIFICE-1 RA Mrk Jt VA 1., kort �. 11-7 RA Mrk Jt = WELL DATA 11Tag PBTD @ 10,854'SLM PTD:214-177 12� 0 2.50"Gauge Ring API: 50-133-10109-03 2/01/15 Lease: FEDA-028997 4-1/r t.L. 6"Hole Spud Date:12/24/2014 TD=11,003'MD—10,829'TVD Max Deviation 34°@ 10,402' Tree cxn: 3.5"Bowen PBTD=10,870'MD—10,716'ND Max Dogleg 10.8°/100'@ 9,068' Lift Threads: 3-1/2"8RD Downhole Revised:2/04/15 Updated by STP 2/06/15 Hilco. _Energy Company Composite ;port Well Name: SCU 41 B-04 Field: County/State: ,AK (LAT/LONG): :vation(RKB): 18 API#: Spud Date: Job Name: 1413459P SCU 41B-04(SCU 41A-04 ST)PRE-DRILL Contractor AFE#: 1413459P AFE$: Activity Date 12/14/2014 Rig down on well SCU 21C-04, move all rig modules off location.,Felt,liner on well SCU 41A-04(SCU 41B-04),spot sub,set draw works,derrick,gen sets, pump houses, 1 pit section.,Start hooking up utility lines,prep derrick for raising. 12/15/2014 Drop travel beam out of sub,hang windwalls,spot top drive on rigfloor,spot pumps,pits,boilers and rig up he same. Put down felt and containment for pipe shed.,Change out cylinder on derrick and raise same.Spot catwalk with choke house,pipe sheds and hook up same,steam,electrical, Hyd.,Cut and slip 136'of drilling line,prep derrick to be raised,pick up torque tube and telescope the derrick up. Put top drive in blocks and install kelly hose. 12/16/2014 Continue to R/U on SCU 41A-04.R/U hydraulic and steam lines.Spot gen 3, Halliburton trailers.Replace gate seals in pits. Replace broken bolts on iron ruffneck face plate.Perform 125 day inspection on draw works.Check air operation to rig floor motor.,C/O swivel packing. Install saver sub,bails.Function test top drive. Install 2"bleeder valve and lines.R/U tongs,replace riser cables in pits.,R/U fuel lines to boilers.Fill pits with 359 bbls of produced water. Change bed rubbers on#1 shaker.R/U centrifuge,gas buster line. Install cuttings box chute. Prime and pressure test mud pump and lines., Install Gas buster hose and choke hose from catwalk to I/A,install hose from stand pipe to tree valve to kill well. Pressure test lines to 500 psi. Note: tubing 240 psi, IA 125 psi.,PJSM, Kill well pumping 8.4 ppg produced water down tubing at 5 bpm,50 psi,taking returns thru choke and gas buster,as fluid started up the annulus the tubing pressure increased to 1,500 psi with 40 psi on the casing.Hole capacity is 215 bbls and we pumped a total of 280 bbls with no returns., Flow Check while hauling produced water,no flow.,Accept rig @ 06:00. 12/17/2014 Crew change, PJSM with Cameron-set BPV. N/D tree.,N/U 11"5M BOPE.,Continue to N/U BOPE,install 2-3/8"ram in lower BOP. Ram configuration- upper 2-7/8"x 5"VBR,middle-blind ram., R/U test equipment,AOGCC rep Jim Regg waived witness @ 9:49 am on 12/17/14. Shell test BOP to 3,500 psi. Test BOPE using fresh water,test choke manifold valves,upper and lower IBOP,upper pipe ram w/4-1/2"test jt,outside kill line valve and HCR to 250/ 3,500 psi 10 min ea. Chart tests. Perform bleed test on manual and electric choke. #1 choke valve F/P. 12/18/2014 Continue to test BOPE with water.Pull BPV,install TWC.Test upper pipe 2-7/8"VBR ram with 4-1/2"and 2-7/8"test jts,test lower 2-3/8"ram with 2-3/8" test jt,blind ram,HCR kill and kill valve,HCR,3"manual valve,FOSV,Dart valve,upper and lower IBOP to 250/3,500 psi 10 minutes ea.Test annular with 2-3/8"and 4-1/2"test jts to 250/2,500 psi 10 minutes ea.Chart all tests.Perform accumulator draw down test.,R/D test equipment,blow down choke and gas buster., PJSM, R/U Weatherford power tongs and 2-7/8"handling equipment.,M/U landing jt and top drive.Close annular,line up to closed choke. Back out LDS per cameron rep. Pull 80k to unseat hanger,P/U 2'.,Open choke,pump 8.4 ppg produced water down tbg 5 bpm,pump 91 bbls before seeing tbg pressure,continue to pump 5 bpm, 1,450 psi.See returns out gas buster @ 180 bbls pumped.shut down pump,well on vac.Open annular, close choke.,Pull 90k,packer sheared at 15k over string wt.pull hanger to rig floor©10,237'. Establish loss rate @ 140 bph,pump down backside using rig pump©3 bpm keeping hole full. L/D landing jt and hanger. Blow down choke,gas buster and top drive.,POOH from 10,237'to 5,171'L/D 2-7/8" production string filling backside @ 70 bph with 8.4 ppg produced water. Current losses to well:531 bbls of produced water. 12/19/2014 Trip out lying down the 2 7/8"casing F/5000'to 966'.Wipe down each jt and put protectors on each end.,Continue tripping out with the 2 3/8"tubing F/966' to the packer and entry sub,lay down same., PJSM,Close blind ram. R/D Bell nipple,N/U lubricator.R/U Priority a-line M/U 12.64 1/2"CIBP_Baker#10 setting tool,3 1/8"CCL with quick change,Pressure test lubricator to 250/3000 psi 10 min ea.Open blind ram.,TIH with e-line,locate 4 1/2"collar @ 10359'.Set 4 1/2"CIBP Cad 10367'(GIBE set_8'=kelow 4 1/2"collar and 50'above top perf). POH with setting tools. Fill wellbore,38 bbls.Well is static.,R/U test equipment,close blind ram,Monitor 0/A.Attempt to test bridge plug,pressure up using mud pump to 1500 psi w/no further pressure increase,5 bbls pumped,shut off pump.Pressure bled to 0 psi.Check surface equipment.Attempt to re-test with same results.Open blind rams.R/D test equipment,well remains static.,M/U 3"x 40'bailer,3 1/2"CCL and XOs,load w/12 gallons of 16.6 ppg cement.RIH,tag CIBP on depth @ 10367',bail cement. POH, Load bailer w/12 gallons of cmt,RIH to 10349'and bail remaining cmt to 10332'(35'of cmt on top of plug)POH. Load 12 gallon barite slurry in bailer. RIH to 10332',bail 14 ppg barite slurry on top of cmt plug.POH,L/D tools. R/D wire line. Last 24 hrs well took 606 bbls of produced water.Total losses 1137 bbls of produced water. 12/20/2014 Nipple down the wire line lubricator and install flow nipple., Install wear bushing with a 6 3/8"ID,Service rig and topdrive.,Mobe drill pipe and strap same., M/U 6"bit-MX-18HDX Tricone bit with 3 x 14 jets,7"csg scaper,bit sub,xo=7.79',Static loss rate @ 21 bph.,Drift and single in the hole w/4 1/2"drill pipe scraping 7"casing to 4500'.Fill pipe every 2500',Continue to single in the hole with 4 1/2"drill pipe from 4500'to 9379'just above 4 1/2"liner top @ 9383'.Fill pipe every 2500',use continuous hole fill on trip in,hole took 200 bbls on TIH.,M/U top drive, Break circulation,pump 500 stks,shut down pump. Establish loss rate-continues©21 bph. Blow down top drive.,POH with 7"scraper assy from 9379'to 3400',use continuous hole fill on trip out. Last 24 hrs well took 438 bbls of produced water.Total losses 1575 bbls of produced water. 12/21/2014 Continue to POH with 7"casing scraper from 3400', L/D casing scraper assembly., PJSM,R/U weatherford tongs and handling equipment. M/U Haliburton 4 1/2"RTTS assembly.Single in the hole with 2 7/8"drill pipe to 1000',RIH with 4 1/2"drill pipe in derrick from 1000'to 9422',84'below 4 1/2"TOL. P/U 148K,S/0 148K. Note: lost 87 bbls on trip in the hole.,Set RTTS @ 9422',attempt to pressure up on CIBP,leaking by RTTS,release RTTS.RIH and re- set RTTS©9495', Pressure up on plug,RTTS holding but leaking past CIBP.Close annular,monitor 0/A. Pressure up on backside to 2600 psi,lost 50 psi in 5 minutes,good test. Bleed off pressure,open annulas. Release RTTS,RIH from 9495'to 10278'.P/U 162K,S/0 161K,Set RTTS @ 10278',attempt to test CIBP,leaking by plug.Close annular,monitor 0/A.Pressure up on backside to 2600 psi,bleed off 50 psi in 10 minutes.Good test on I/A to surface. Confirm CIBP not holding. Bleed off pressure,open annular.Release RTTS., Blow down top drive,POH from 10278'to 1000',R/U power tongs and 2 7/8" handling equip. POH from 1000'L/D 32 jts 2 7/8"drill pipe.L/D RTTS.Trip out of th hole took 110 bbls over calculated displacement. Last 24 hrs well took 287 bbls of produced water.Total losses for SCU41A-04 1862 bbls of produced water. 12/22/2014 R/D Weatherford tongs and power unit.,P.ISM,R/U Priority e-line and lubricator.Pressure test lubricator to 250/3000 psi 5 min ea.Open blind ram.RIH and set 4 1/2"CIBP @ 10297',POH.,( blind ram,monitor 0/A,attempt to test CIBP,pressur )2300 psi,leaking by plug.Open blind ram.,Rig service,grease crown sheaves,drawoi. range oil in draworks transmission.,Wait on haliburtor, t"EZ Drill plug.,Pressure test lubricator to 250/ 3000 psi 5 min ea.RIH and set 4 1/2"EZ drill plug @ 10275',POH.,Close blind ram,monitor 0/A,test EZ drill plug to 2600 psi for 30 charted minutes.No pressure loss.Good test.Bleed off pressure,open blind ram.,M/U 3"x 40'bailer,3 1/2"CCL and XOs,load w/12 gallons of 16.6 ppg cement.RIH,tag 4 1/2"EZ drill plug on depth @ 10275',bail cement.POH,Load bailer w/12 gallons of cmt,RIH to 10256'and bail remaining cmt to 10240'(35'of cmt on top of plug)POH.UD bailer assembly.,R/U 7"CIBP and CCL tools,RIH,set CIBP @ 9086'(5'above collar©9091')POH,R/D e-line.Remove XO flange for lubricator.,M/U bell nipple and lines,Pull 6 3/8"wear bushing,Install test plug.With 3 barriers in place,C/O lower 2 3/8"pipe ram,install 2 7/8"x 5 1/2" VBR.,Last 24 hrs well took 113 bbls of produced water.Total losses for SCU41A-04 1975 bbls of produced water. 12/23/2014 Cont NU flow riser and button up ram doors after ram change.,Test 2 7/8"x 5 1/2"VBR to 250/3500 psi at 10 minutes each on chart.R/D test equipment., Rack and Tally Baker whipstock/milling tools.M/U BHA.BTM trip anchor,WS slide,6"window mill,5 7/8"WMM,Flex jt,6"WMM,floatt sub,UBHO sub, xo,Single in the hole with 30 jts 4 1/2"HWDP=964.74'.,TIH from 964'to 9044'at 1-2 min per stand.Easy in and out of the slips.,Fill pipe,R/U Pollard e- line with Gyro tools and side entry sub.M/U 1 stand and top drive.P/U 160k,S/O 160k.,RIH with Gyro on e-line to 9000'@ UBHO sub.latch gyro in UBHO sub,with tool face of 354 deg,work pipe down in 10'intervals 3 times.Check tool face,338 deg.turn pipe 1/8 turn to right,work torque down in 10'intervals 3 times.Check tool face @ 0.52 deg,P/U e-line 30',RIH and retag UBHO sub.Check tool face @ 2.2 deg.,POH with e-line.UD side entry sub and gyro 1.. tools.R/D e-line.,Set top drive torque @ 12.5K.M/U stand and top drive.RIH and tag CIBP @ 9073'MD.Set down 20K and set anchor.P/U 10K over to verify anchor set.Set down 40K and shear whipstock bolt.P/U 5'TO 9050'.Whipstock orientation is at 2.2 deg as per version#3 of directional plan., Displace with 9.8 ppg drilling mud pumping 5 bpm,1800 psi.P/U 160K,S/0 160K,ROT 160K.95 RPM,torque off 4300#.Mill window as per Baker Rep. Time mill 6"window from 9055'to 9062'miming 355 gnm 1970 psi, 1.5-2K wt on mill.95 RPM,average torque @ 4-7K.Ditch magnets and catch pans in place,start seeing metal @ shaker after 2'of window milled.,Total losses for SCU41A-04 1975 bbls of produced water.,Reporting now rolling over to "Drilling" Hilca ,Energy Company Composite ;port Well Name: SCU 41B-04 Field: County/State: ,AK (LAT/LONG): evation(RKB): 18 API#: Spud Date: 12/24/2014 Job Name: 1413459-SCU 41B-04 (SCU 41A-04 ST)DRILLING Contractor AFE#: 1413459D AFE$: Activity Date Ops Summary 12/24/2014 Cont milling 6"window from 9062'to BOW at 9068',then 20'of new formation from 9068'to 9089'.Rotating wob 1 to 2K,355 gpm-2060 psi,95 rpm-4640 fUlbs on bott torque.MW 9.8 ppg/50 vis.BGG 12 units.Had good indication of cement at 9056'.ROP 1 to 10 fUhr.Pumped hi-vis sweep around at 9087'while drilling last 2'of new formation.Reamed hole and window a couple times to ensure clean window opening.;Cont circ sweep around at 297 gpm-1770 psi to clean up hole and casing. Recovered total of 162 lbs of metal from milling window.;RU chart recorder,circ through kill line to eliminate any air,close upper rams.Pumped 35 strokes(2.5 bbls)to achieve 1278 psi and held 10 minutes.PSI dropped from 1278 to 1254 in 10 minutes.Bled off and RD chart recorder.;Mixed 15 bbl dry job while flow check well.No flow.Pump dry job,blew down topdrive and mud Iines.;POOH from 9067'to 964'.LD 4 joints HWDP not needed in directional BHA.Rack 13 stands of HWDP in derrick.L/D window mill assembly.Correct displacement on trip out.Upper watermelon mill less than 1/16"under gauge,Lower watermelon mill in gauge,starter mill in gauge.Clear rig floor.;Install 6 3/8"wear bushing.;Service top drive and draworks.;PJSM,load tools to rig floor,M/U 6"Directional BHA#3.6"PDC bit, 1.5 deg mud motor,5 3/4"stab,flt sub,DM Collar,scribe MWD to mud motor with offset @ 294.40 deg.M/U slim phase 4 collar,PWD collar,TM collar,and UBHO sub.Note:2-3/4"set screws missing on UBHO sub,chase threads with tape.Orient UBHO sub to motor bend,install set screws with loctite and torque screws to 200#.Uplink MWD data.M/U NMFC w/corrosion ring on top,XO and 1 std of HWDP,Shallow hole test MWD.Run 5 stds and single HWDP,M/U XO,JAR,XO©535'. 140 bbls of trash fluid hauled to KGF. 12/25/2014 RIH with remaining HWDP from 535'to 957'.Cont RIH on 4 1/2"DP from derrick to 5375'.;PJSM,prep rig floor,single in hole 32 joints of 4 1/2"DP from 5375'to 6368'.;Prep rig floor,cont RIH with 4 1/2"DP out of derrick from 6368'to 8972'and MU topdrive.Fill pipe.;With pipe full,PJSM,cut and slip 68'of drill line, calibrate block height and check crown saver.;RIH from 8972'to 9070',MU topdrive and with pump at idle,wash down and tag bottom at 9089'.Stop pump,pull back up hole with no issue in or out of window(TOW 9055',BOW 9068').;PJSM,RU Pollard e-line and Gyro Data tool,MU side entry sub and topdrive.Park pipe @ 9068'RIH with e-line,seat into UBHO sub.;RIH passing thru window with pumps off,park DP 3'below BOW @ 9070',P/U and reseat 3 times with e-line to confirm 323 deg tool face each time.Work pipe annd verify tool face,reconfirm Gyro tool face,344 deg.P/U 172K,S/O 164;RIH to 9084,circulate out gas, peaking©1937u,after BU receding to 27u.No pit gain.;Drilling 6"production hole,Slide from 9089'to 9092'using Gyro directional data until MWD tools exit window.Pumping 260 gpm,2050 psi.WOB 2-3K,100-150 DIFF.MW 9.8 ppg,60 vis.;Gyro not reading tool face,P/U 9064'with side entry sub at rig floor,Found damaged cable just above e-line cable clamp.POH with e-line.Break out e-line side entry sub,L/D Gyro tools.Spool e-line on unit.Monitior well using trip tank. Another e-line unit on its way from Pollard WL.;Wait on e-line unit.Park bit @ 8975',break circulation every 20 minutes to keep from freezing,monitor well using trip tank,well is static.;Spot e-line unit,PJSM,Re-head and R/U e-line.M/U gyro tools and side entry sub. 12/26/2014 Cont RU Pollard e-line sheaves and gyro tool,MU Gyro Data side entry sub with 4 1/2"pup joint on top.Insert e-line cable and attach head to wire.Stab into joint in mousehole and MU same on bottom of side entry sub.Back wrap e-line 5 1/2 wraps around this assembly.Stab and MU this assembly on drill string.5 1/2 back wraps is perfect to spin up CDS-40 joint and torque same.;RIH with e-line and seat gyro tool numerous times in UBHO sub.Tool face at 358 deg.Install line clamp on side entry sub and tighten packoff.Pump at 220 gpm down drill string to check for leaks,no leaks in side entry sub.;Cycle pump to allow Gyro Data to put tool into steer mode(shut down pump 4 minutes and re-start),start pump at 224 gpm-1624 psi,ease down and tag bottom at 9092'.Resume slide drilling 6" hole from 9092'to 9109',Sliding wob 1K,225 gpm-1623 psi,46 to 150 psi diff,ROP 1 to 15 ft/hr,MW 9.8 ppg/vis 53,BGG 4 units.No losses.;Drilling is extremely slow.Pumped hi-vis nut plug sweep at 9102'with no increase in cuttings or ROP.Cuttings samples showed loose sand to tufts and high clay content sandstone. Alternated pump rate from 225 gpm to 269 gpm.Average ROP 1.7 FPH.Decision made to POH due to slow ROP.;POH with e-line,L/D gyro tools and side entry sub.R/D e-line sheaves.;Pump hi vis sweep around,BU gas peaked @ 225u,no increase in cuttings©shaker with sweep returns. Flow check well,well is static.Pump dry job.Blow down top drive.;POH from 9109'to 1500',correct fluid displacement POH. 12/27/2014 POH with 6"directional BHA#1 from 1600'.Plugged in and shut off MWD tool and rack back same.LD motor due to overly tight stator.Motor had no play in shaft when set down on bit.Will C/O as a precaution.6"HDBS PDC bit graded at 2-7-CT-G-X-I-PN-PR.Hole fill was proper entire trip and no flow or loss prior to closing blinds when out of hole.;PU new mud motor,MU new HDBS 6"PDC jetted w/5 x 11's.Set motor up with 1.5 deg bend.Cont RIH to MWD, download/upload same.Cont RIH with remaining BHA and HWDP.Shallow pulse test was good.Cont RIH filling pipe every 30 stands.RIH to 9063',P/U 165K, S/O 165K.M/U single,fill pipe.;Circulate BU©9098',Gas peaked @ 537u.PJSM,R/U e-line sheaves while circulating.;Break out single,set in mouse hole.P/U side entry sub with 15'pup.M/U Gyro tools,M/U same to jt in mouse hole,install e-line cable clamp. M/U side entry sub and single to drill string.Remove e-line clamp.RIH with e-line and gyro tools,seat gyro tool several times in UBHO sub,tool face 153 deg.;Cycle pump to allow Gyro Data to put tool into steer mode, pump 269 gpm @ 2030 psi,tag on depth @ 9109'.;Slide drilling 6"hole from 9109'to 9113'pumping 260 gpm,202 psi.Drill 2'with 2-3K wob then increasing to 5-7K.Slow PR @ 1 fph.MW 9.8 ppg,vis 54.No Iosses.;70 bbls of junk fuid hauled to KGF. 12/28/2014 Cont slide drilling 6"hole from 9113'to 9115',sliding wob 10K,265 gpm-2153 psi,8 to 164 psi diff,ROP+/-1 ft/hr,MW 9.8 ppg/59 vis.Basically have no ROP.;PU off bottom,stop rig pump,remove line clamp on side entry sub,POOH with e-line and gyro tool.Install line clamp and lay down side entry sub assembly.;MU stand and topdrive,break circ and start rotation at 20 rpm.Ease down and tag bottom,rotary drill from 9115'to 9128'.Rotating wob 7 to 10K,265 gpm-1820 psi,20 rpm-4300 ft/lbs on bott torque,5 to 25 ft/hr ROP,cuttings samples indicate 30%siltstone,70%sandstone of a very hard nature.;CBU 1 x while reciprocating string,keeping bit and stab outside of window.;Lay down single joint,PU and MU side entry sub assembly,RIH with gyro tool on e-line.Seated gyro tool 4 times,tool face at 13 deg azimuth,install line clamp on side entry sub.Cycle rig pump to put gyro tool into steering mode.;Resume slide drilling from 9128' to 9135'.Sliding wob 5 to 15K,267 gpm-2281 psi,28 to 158 psi diff,1 to 25 fUhr ROP.;Continue to drill,sliding from 9135'to 9151'pumping 267 gpm, 1900 psi. 10 to 30 psi diff.ROP 3-6 fph.Difficult wt to bit transfer,rock string with rotary attempting to get wt to bit.;PU off bottom to 9128',stop rig pump,POOH with e-line and gyro tool. Install line clamp and set single and side entry sub assembly in mouse hole.;M/U stand,rotary drill from 9151'to 9161'pumping 266 gpm,2200 psi. WOB 8K,20 rpm,4800#torque on.Average ROP 8 fph.Samples show siltstone with trace of sand.;L/D single,M/U side entry sub assy.Remove e-line clamp. RIH with gyro tools on e-line.Seat gyro tool 4 times,tool face at 307.94 deg,install line clamp at side entry sub.Cycle pump to put gyro tool into steering mode.;Tag bottom,resume slide drilling from 9161'pumping 247 gpm,2450 psi.MW 9.8 ppg,vis 51.No Iosses;70 bbls of trash fluid hauled to KGF. 12/29/2614 Cont directional drilling 6"hole.Slide from 9161'to 9166'.Sliding wob 5 to 15K,266 gpm-2748 psi,2 to 168 psi diff, 1 to 4 ft/hr ROP,BGG 3 units,MW 9.8 ppg/vis 53,no flow and no losses.;At 911 -arty DD confident we no longer need gyro data for stew 'U off bottom,shut down rig pump,unclamp wire, POOH with gyro tool on e-line,RD Pollai aline and Gyro-Data side entry sub,release same.The, no surveys at this point as UBHO sub did not exit window and gyro was used for steering only.;Resume directionally drilling 6"hole from 9166'to 9300'.Rotating wob 6 to 12K,266 gpm-2401 psi,65 rpm-4611 ft/lbs on bott torque,5 to 50 ft/hr ROP. Sliding wob 2 to 7K,267 gpm-2268 psi,68 to 116 psi diff, 14 to 45 ft/hr,ECD's at 11.5,BGG 9 units,MW 9.8 ppg/vis 53.Drilling 100%sandstone.Up wt 158K, dwn wt 150K,rot wt 157K.;Cont directional drilling 6"hole from 9300'to 9436'pumping 269 gpm,2350 psi.6-10K wob.65 RPM,torq 7K.Average ROP 60 fph. Formation shows Sandstone with trace of coal. P/U 178K,S/O 160K,ROT 169K.MW 9.8 ppg,vis 51.No losses.ECD 11.40,BGG 21 u.;Saver sub broke out of quil at rig floor while making connection.install new dies in clamp,0/0 saver sub,torque to 23000#;Cont drilling from 9436'to 9616'pumping 268 gpm,2080 psi.6-10K wob,65 rpm,torq 7K,.Average ROP 26 fph.MW 9.8 ppg,vis 50.ECD 11.4,BGG 28u.No losses.Slide 15'every stand drilled building up to 13.8 inc. P/U 180K,5/0 162K,ROT 171K.Samples show 80%siltstone and 20%sand.Currently 11.99'above the line and 11.66'right of the line.;70 bbls of trash fluid hauled to KGF. 12/30/2014 Cont directional drilling 6"hole from 9616'to 9903'.Rotating wob 2 to 3K,269 gpm-2435 psi,80 rpm-6300 ft/lbs on bott torque,42 to 100 ft/hr ROP.Sliding wob 1 to 5K,268 gpm-2190 psi,34 to 71 psi diff,9 to 48 ft/hr ROP,MW 10.4 ppg,BGG 21 units. EHS field coordinator John Coston stopped by for a visit.No issues to report.Up wt 180K,dwn wt 160K,rot wt 172K at 9903'.;`At 9597'we had no flow.At 9654'well began to flow 3 bph on connections.At 9715'flow has increased to 13 bph.Notified Drilling Engineer and start increasing MW to 10.Oppg while drilling.Connection gas jumped to 9547 units then dropped to 6 units in 5 minutes, gas cut MW down to 7.4 ppg.We had recently drilled through the SR_TYNKCT16A 8'coal estimated top at 9645'.At 9777'well flowing at 10 bph with 10.0 ppg mud in hole.Increased MW to 10.2 ppg while drilling.Connection gas maxed out at 1961 units.;At 9839'well still flowing at 10 bph with 10.2 ppg MW.We had drilled through the TEMP_CT_7 12'coal estimated top at 9807'.Discussed with Drilling Engineer and increased MW to 10.4 ppg while drilling.Connection gas maxed out at 6761 units.ECD's at 12.0 ppg with MW of 10.4 ppg.At 9901'well flow increased to 21 bph with 10.4 ppg MW.Discussed with Drilling Engineer and increased MW to 10.6 ppg while drilling.Connection gas maxed out at 7082 units.;Cont directional drilling 6"hole from 9903'to 10150'.Rotating wob 3K,269 gpm- 2450 psi,80 rpm-8240 ft/lbs on bott torque,42 to 100 ft/hr ROP.Sliding wob 3 to 5K,270 gpm-2520 psi,80 psi diff,9 to 48 ft/hr ROP,MW 10.6 ppg,BGG 15 units. Up wt 184K,dwn wt 163K,rot wt 171K at 10150'. Flow @ connections decreased F/20 bph-T/16.5 BPH @ 10,064'MD. No gain while drilling.;Service rig and topdrive.;Cont directional drilling 6"hole from 10150'to 10,213'.Rotating wob 3K,270 gpm-2475 psi,80 rpm-8240 ft/lbs on bott torque,42 to 100 ft/hr ROP.Sliding wob 3 to 5K,270 gpm-2525 psi,80 psi diff,9 to 48 ft/hr ROP,MW 10.6 ppg,BGG 12 units. Up wt 184K,dwn wt 163K,rot wt 171K. ECD's @ 10,190'MD=12.2. Flow @ connections continue @ 16.5 BPH. No gain while drilling.Drilling in 90%sand and 10%siltstone.Last survey had us 14'high and 4' right of the line.;;Hauled 280 bbls trash fluid to KGF,total trash fluid hauled 700 bbls.Hauled 0 bbls cuttings to KGF,total cuttings hauled 40 bbls. 12/31/2014 Cont directionally drilling 6"hole from 10,213'to 10,274'.Rotating wob 1 to 5K,269 gpm-2489 psi,85 rpm-7900 ft/lbs on bott torque,25 to 60 ft/hr ROP.MW 10.6 ppg/vis 44,ECD's at 12.2 ppg.Well flow has decreased from 21 bph to 9 bph over the last connection,with no indication of losses to the well.Discussed with Drilling Engineers and decision made to stop here,increase MW to 10.8 ppg,then POOH for our bi-weekly BOP test.We are currently+/-59'above the SR_H1ST(Hemlock 1 Sand Top).Pumped hi-vis sweep at 10,254'.;Rotate and reciprocate staying 20'off bottom while increasing MW from 10.6 to 10.8 ppg, circulate sweep out of hole.Up wt 162K,dwn wt 160K,45 rpm-6900 ft/lbs off bott torque.Had 10%increase in cuttings to surface.Racked back one stand every 30 minutes to reduce trenching while circulating/increasing MW.BGG 5 units,no losses and no gains.With good 10.8 ppg in/out,shut down and flow check. 10 bph flow.;Pull up hole 5 stands(wet)from 10,181'to 9869'.Hole in good shape.Still have 10 bph flow.Notified Drilling Engineers and decision made to trip to bottom and increase MW from 10.8 ppg to 11.0 ppg.Trip in hole 5 stands to 10,204'with no problems.;MU topdrive and begin working drill string from 10,204'to 10,162',circulating at 267 gpm-2198 psi,rotating 45 rpm-6600 ft/lbs off bott torque.Mix and pump 11.0 ppg mud.Had a max of 7954 units which dropped off, then spiked again at 7414 units,which dropped off after 10 minutes to 21 units,then down to 5 units.We also dumped 25 bbls watered back mud(9.5 ppg).With good 11.0 ppg in/out flow check is at 6 bph.Decision made to pull to window and check flow.;Pulled up hole from 10,204',190K up wt,pipe pulling dry,fluid not dropping in annulus.Stopped at 9487'and well flowing at 1.8 bph.Hole in excellent condition.Cont POOH with no issue pulling BHA through window at 9055'. Once BHA was inside 7"casing,fluid on the backside started to drop as we pulled pipe.Pipe continued to pull dry inside casing.Stopped at 7975'and flow is initially at 1.5 bph.After 20 minutes flow increased to 5 bph and to 7 bph after 40 minutes.We had no hole fill at this point.;Notified Drilling Engineers of well flow. Built 25 bbls of 13 ppg hi-vis pill(220 vis)while monitoring well.Pumped and spotted 20+bbls 13 ppg hi-vis pill in 7"casing(5 bbls outside string-15 bbls inside DP).PJSM with new crew(new Driller,Derrickman and a couple Floorhands to rig);Cont POOH from 7975'to 3448'MD. No obstructions. Showed 14 bbl gain for these tripping depths. Pulled dry until 7780'MD. Pulled wet from there to 3448'MD.;Flowcheck @ 3448'MD. 5.5 BPH flow. Build and spot 40 bbls, 13 ppg, 150 vis weighted pill @ 3448'MD. Left 25 bbls in pipe for slug. Flowcheck after spotting weighted pill showed slight decrease in flow @ 5.3 BPH. Pumped pill @ 133 gpm,534 psi,17%flow,5 units BGG.;Continue POOH F/3448'-T/45'MD. No obstructions. Pulled dry. 41 bbl total gain for entire trip.;Download MWD. Flowcheck while downloading-4.2 BPH flow.;Drain BHA and changeout TM collar. 1/1/2015 Flushed mud motor with water and drain,break off bit,motor in good shape.6"MM55 HDBS PDC bit graded at a 2-2 and came out very clean with no plugged jets.Well flow increased from 4 bph to 10 bph over the last hour.Notified Drilling Engineer and decision made to call out Halliburton with storm packer,so we can perform our bi-weekly BOP test.Also discussed MU BHA and start in hole for hang off weight below storm packer.;Monitored well psi with blinds closed while prep to MU BHA.Built to 216 psi after an hour,bled off and opened blinds,still flowing at 10 bph.Called out Halliburton Rep and storm packer.Total Safety was on location and calibrated/tested gas detection equipment.;MU new HDBS MM55 PDC jetted with 5 x 11's,scribe motor,RIH LD HBHO sub,RIH to Slim Phase 4 collar,plug in and download same,cont RIH with remaining BHA components and 13 jnts HWDP.MU topdrive and shallow pulse test in the larger ID casing. Good test.Cont RIH with jars and HWDP to 955'.;MU Halliburton storm packer on top of 4 1/2"HWDP,RIH one stand and set same at 59'.+/-17K BHA weight below packer.Rack back stand and LD run tool.Close blinds for packer test,discovered leaking koomey hose.;Change out koomey hose(blinds).;Line up on kill line and with blinds closed,tested casing/storm packer to 1700 psi for 5 minutes.Good test.Bled off,blew down topdrive.;MU wear ring retrieval tool,BOLD's,pull wear ring,install test plug.Fill stack,RU chart recorder,circ through test lines,close up-per rams,shell test stack at 2500 psi,good test.;#1-Test upper rams, choke and kill HCR's,TIW,#2-Test inside kill and choke manual valves,#3-Outside manual kill valve,#4-Annular,#5-Lower pipe rams and dart valve,#6- Koomey drawdown,#7-Blinds,#8-Upper IBOP(topdrive),#9-Lower IBOP(topdrive),#10-Blinds.Tested choke manifold on previous trip out of hole.No failures. Total test time 6 hrs(includes choke manifold).Witness waived by AOGCC on 12-29-14.Witness waived by BLM on 1-1-15.;Called out Halliburton Stormpacker Rep,blew down choke line,manifold and degasser lines.RD test equipment,pull test plug,install 6 3/8"ID wear ring.;PU stand,MU XO and packer retrieval tool, RIH to just above packer,MU TIW on top of stand and close same,engage storm packer w/20 turns right hand. Equal psi below packer to retrieval string. Observed psi slowly increasing to a max of 682 psi over 15 mins. Bleed off psi. Close annular and release element on packer. 0 psi on casing side. Open annular and attempt to circulate. Psi up to 480 w/no circulation. Pull packer as per halliburton rep. 33k up, 22k dn. Well flowing @ 11 BPH once packer was disengaged.;Wear bushing came out w/packer assy. Clean and laydown storm packer. Re-install wear bushing and RILDS. Kelly up and break circulation. Pump @ 133 gpm,494 psi,18%flow,381 max gas.;Stage in hole. TIH F/955'-T/1637'MD.Observed 697 units gas and rising.;Circulate and condition mud @ 1637'MD. Pump @ 135 gpm,515 psi,19%flow, 1874 units max gas;Continue stage in hole. TIH Ff 1637'-T/2768'MD. Observed 1431 units gas and rising.;Circulate and condition mud @ 2768'MD. Pump @ 135 gpm,590 psi, 19%flow,8890 units max gas. Condition mud to 10.9 ppg;Continue stage in hole. TIH F/2768'-T/4388'MD. Observed 2992 units gas and rising;Circulate and condition mud @ 4388'MD. Pump @ 135 gpm,629 psi, 19%flow. Circulate out and overboard 8.3 ppg water from wellbore. Balance wellbore w/10.9 ppg mud before continuing trip. 9980 units max gas.;;Hauled 105 bbls Class II fluid to KGF,Total Class II fluid 940 bbls. Hauled 0 bbls cuttings to KGF,Total cuttings hauled 40 bbls 1/2/2045 Cont to circ and condition mud to a 10.9 ppa at 4388'(tripping in with 6"directional BHA).134 gpm-634 psi(keeping pump rate low to avoid bit damage inside , casing).Had a max of 2874 units gas.;N id 10.9 ppg in/out,blew down topdrive and continued t 'i hole from 4388'to 6009'.;At 6009'MU topdrive, break circ at 134 gpm-700 psi.Did one fk with a max of 8270 units gas.With return MW at 9.6 p, 4mped a total of 85 bbls watered back mud,lowest ppg was 8.4.Cont circulation until good 10.8 ppg in/out.Using the lighter mud returns to reduce surface volume MW from 11.0 ppg back to our original 10.6 ppg for drilling.;With good 10.8 ppg in/out blew down topdrive and continued to trip in hole from 6009'to 9027'.;At 9027'MU topdrive,break circ at 134 gpm-707 psi.Did one full circ with gas spikes at 6588 and 6740 units.With return MW at 9.3 ppg,dumped a total of 164 bbls watered back mud,lowest ppg was 8.4.Cont circulation until good 10.7 ppg in/out.;With 10.7 ppg in/out,cont ease in hole exiting window at 9068'.Encountered tight hole at 9122'(BHA still in window,bit in sandstone formation).PU,MU topdrive and break circ at 249 gpm-1986 psi,rotate at 20 rpm-4600 fUlbs.;Slowly wash down from 9122'to 10,274'MD.Had gas spike of 8106 units then dropped right off to 5 units.MW at shakers 10.6 to 10.7 ppg.ECD's at 12.0.At 9215'increased to 40 rpm-5496 ft/lbs torque.Getting a fair amount of sand and small coal on shakers. Pump @ 250 gpm,2110 psi,30%flow,increased to 50 rpm,6.5k tq. 8.5 BPH water flow prior to drilling ahead.;Drill ahead F/10,274'-T/10,448'MD. Pump @ 260 gpm,2110 psi on,104 diff psi,29%flow,80 rpm,7.2k tq on,5.4k tq off. ECD=12.13 ppg, 180k up, 158k dn, 162k rot, Max gas=1102 units,BGG=54 units. Currently drilling in the H3 formation as per projected tops.;;Hauled 0 bbls cuttings to KGF for a total of 40 bbls,Hauled 350 bbls class II junk fluid to KGF for a total of 1290 bbls, Hauled 0 class II cement to KGF for a total of 0 bbls Last survey showed us 10'high and 1'left of line 1/3/2015 Cont drilling 6"hole from 10,448'to 10,862',rotating wob 2 to 6K,259 gpm-2479 psi,80 to 90 rpm-8475 fUlbs on bott torque,12 to 48 ft/hr ROP,BGG 55 units, connection gas 500 to 600 units,mud weight 10.6/vis 46,well flows at 6.5 bph during connections.No gain or loss while drilling.Kept ROP at 50 ft/hr or less to accomodate sample catchers obtaining samples every 10'.From 10,600'to 10,700'there was virtually no show of flouresence on cuttings samples.From 10,715' to 10,862'flouresence ran 10 to 70%on cuttings.;Cont drilling 6"hole from 10,862'to TD at 11,000'md/10828'tvd.Rotating wob 7k, 259 gpm,2500 psi on,190 psi diff,30%flow,12.2 ppg ECD's,180k up,152k dn,165k rot,42 units BGG,553 units max gas(connection gas). 6.5 BPH flow between connections w/pumps off,no gain while pumps on. TD confirmed w/Geo(John Serbeck). 50 ft/hr ROP limit for 10'samples. TD @ 12' low,26'left,28.6'ctr to ctr;Circulate and condition hole reciprocating pipe @ 11,000'MD. Pump @ 245 gpm,2195 psi,29%flow,12.1 ppg ECD's,50 rpm,6.8k tq w/36 units BGG. 6.5 BPH flow prior to trip. Pump 20 bbl 10.6 ppg,250 vis sweep w/no increase in cuttings.;Trip out of hole F/11,000'-T/9,033'MD. Blow down top drive. Overpull 30k off btm and had to rotate off wall. Saw 15-25k overpull for the first 300'of trip but was still able to pull on elevators after first stand. Saw no obstructions when pulling BHA through window. Calculated proper pipe displacement for trip w/flow showing slight trend down. 3.4 BPH flow after trip.;Trip in hole F/9,033'-T/11,000'MD. MT trip tank,Flow check 3.4 BPH flow. Wash and ream tight spot @ 10,360'MD. Tripped back through tight spot w/ no obstructions. Continued to btm with no other obstructions.;Circulate and condition hole reciprocating pipe @ 11,000'MD. Pump @ 246 gpm,2046 psi,28% flow,70 rpm,7k tq,13 units BGG,12.1 ppg ECD's. Pumped 20 bbl 10.6 ppg,250 vis w/no increase in cuttings. Spot 50 bbl 10.6 ppg,250 vis pill in open hole. Dumped 35 bbls of water diluted mud while circulating.;Hauled 70 bbls cuttings to KGF for total of 110 bbls,Hauled 350 bbls class II junk fluid to KGF for total of 1640 bbls, Hauled 0 bbls class II cement to KGF for total of 0 bbls. 1/4/2015 POOH with 6"directional BHA from 11,000'to 10,286'(just above Hemlock Sands).Pulled on elevators.First 5 stands had overpull of 40K down to 10K,then no overpull remainder of open hole trip.At 10,286'blew down topdrive and well flowing at 4 bph.Cont POOH from 10,286'into 7"casing window at 9055'.No issue pulling BHA through window.Stopped with bit at 9015'.;At 9015',MU topdrive and pumped 20 bbls hi-vis 13 ppg pill to cap well flow.Worked string slowly to reduce 6"bit wear on 7"casing.Circulated at 135 gpm-833 psi and spotted 5 bbls of the 20 pumped outside the bit.Blew down topdrive.;Cont POOH from 9015', pipe pulling dry.At 5290'pipe pulling wet.MU topdrive and pumped pre-mixed dry job.Blew down topdrive and cont POOH to HWDP.Racked back HWDP and jars to 123'.Plug in and download MWD data.LD PWD,drain motor,break bit,LD motor.6"HDBS PDC bit graded at 2,3,BT,G,X,I,CT,TD;CIean and clear rig floor,remove BHA tools from pipeshed,stage new BHA tools in shed.Well is shut in and monitoring psi build on wellbore via choke manifold. 300 psi over 1 hr 55min. Bleed psi off,blowdown choke and gas buster,open blinds and M/U BHA#6;Pick up BHA#6(948.25')for mad pass w/nukes. Flowcheck prior to trip 7 BPH flow. Used PDC bit,bit sub(non ported float),DM,EWR,ALD,CTN,PWD,TM,NM Flex DC,XO,400'4 1/2"HWDP,Jars w/xo's,400'4 1/2"HWDP. Flow through nukes 20 mins to warm up prior to m/u complete BHA, Shallow test(test good).;Trip in hole w/BHA#6 T/4066'MD. Filling pipe every 25 stds. 14 units avg BGG.;Svc blocks,drawworks,top drive and iron roughneck;Continue trip in hole F/4,066'-T/7,200'MD. Last flowcheck showed 9.7 BPH flow. Fill pipe every 25 stds. 12 units BGG.;Hauled 0 bbls cuttings to KGF for total of 110 bbls,Hauled 65 bbls Class II junk fluid to KGF for total of 1705 bbls,Hauled 0 Class II cement to KGF for total 0. 1/5/2015 Cont RIH from 7200'to 9032'with logging BHA(nukes and 6"PDC bit).Top of window at 9055'.;At 9032',MU topdrive and did one full circulation at 185 gpm- 1275 psi.Had a max of 9877 units gas and dumped a total of 143 bbls watered back mud.(Dumped when MW dropped to 10.4 ppg,and keeping mud when MW was back up to 10.4 ppg).With good 10.6 ppg in/out,blew down topdrive.;Start easing in hole from 9032'and at 9055'string took weight.PU and made numerous attempts very gently,to exit window.String still taking weight at 9055'.Notified Drilling Engineer and also discussed with Drilling Manager.MU topdrive and made several more attempts while pumping at different rates,making 1/4 turns,1/2 turns,full turns and rotating at 10 rpm.At 9055'at 10 rpm,rotating torque would slowly build to the point we stopped rotation at 9800 to 10,000 ft/lbs.Bit weight ranged from 2K to 10K in our attempts.Decision was made to POOH and run the 4 1/2"liner.;Cont to circ at 187 gpm-1351 psi,no rotation,mixed and pumped 20 bbls hi-vis 13 ppg pill and spotted same at 9050',to reduce flow rate while tripping. With pill spotted,blew down topdrive and dropped 2"drift with 68'wire down drill string,to drift for Baker drop down plug.;Start POOH from 9050'dry,racking back 4 1/2"DP in derrick.At the 5810'flow check,well flowing at 1.5 bph.Pulled to 3278'racking back in derrick.;Prep rig floor and cont POOH laying down 4 1/2" CDS-40 drill pipe from 3278'to BHA. UD 8 HWDP and jars,std back remaining HWDP. PJSM UD remaining BHA,unload sources,Download MWD.;UD 8 HWDP and jars,std back remaining HWDP. PJSM UD remaining BHA,unload sources,Download MWD(slow download due to data transfer rate). No scarring or other markings on BHA(except bit). Bit was severely damaged(DBR) 7,8,BT,A,X,I,CT,BHA. All DP and HWDP in derrick drifted w/2.39"rabbit.;Clean and clear rig floor of unneeded tools. Prep floor for next BHA. Flowcheck 9.6 BPH flow. Shut in well while WOO. Monitor SICP and bleed off @ 300 psi as needed.;Svc rig.;Discuss with town about plan forward. Decision made to run in with window mill assv and dress off face of whipstock due to damage on face of hit and inability to exit window with previous BHA Waiting on tools from Baker. 1/6/2015 Prep to MU milling BHA,Baker Rep on location at 6:45,offload tools and stage for PU,monitoring wellbore psi with gauge on annulus,blinds closed.Bleeding off when at 300 psi.;Plant next door shut down and venting large amount of gas.Secured well,killed rig,killed office genset and all personnel evacuated rig. Mustered at main office until notified by Production all clear.Returned to rig,fired up generators light plants and heaters.No issues and no freeze ups.All hands responded in an orderly fashion.;Held PJSM in doghouse with rig team and Baker Reps on PU and MU of milling assembly.;PU single HWDP,MU XO,6.059" upper string mill,6'flex joint,bit sub with float and 6"starter mill.Cont RIH with 9 jnts HWDP,XO's,jars and another 10 jnts HWDP to 634.39'.;Trip in with the mill assembly F/634.39 to 4417'tripping in with stands from the derrick making enough room for picking up singles;Trip in F/4417'to 4896'picking up singles from the walk.Background gas increased peaking at 9800 units with 17 bbls/hr water flow.;Break circulation and pump a bottoms up pumping the gas and water out of well bore.Dumped 33 bbls water cut mud;Continue tripping F/4896'-T/6069'MD. Gas @ 4162 units and rising.;CBU @ 6069'MD. Pump @ 260 gpm,1260 psi, 30%flow. Max gas 9738 units. Dumped 88 bbls produced water while circulating. 11.8 BPH after conditioning mud.;Continue trip in F/6069'-T/9020'MD. Tripped in w/singles T/6601'then tripped out of derrick T/9020'MD.;S/O with no pumps or rotary F/9020'-T/9055'MD. Attempt to S/O through window,Set dn 3k wob @ 9055'MD-no success. Picked up and worked mills dn F/9055'-T/9080'MD pumping @ 260 gpm,1260 psi,60 rpm,4.6k tq off,. Saw erratic tq ranging F/2.6k-T/7.6k ft/lbs tq w/2-3k wob F/9055'-T/9061'then wt fell off and tq leveled out @ 4.6k. Worked through window 6 times before we could pass through without seeing any obstructions or taking any kind of wt. Tripped through window 2 more times to confirm no obstructions(window clean).;Safety Meetings with rig hands,Cut and slip drilling line;Hauled 0 cutting to KGF for total of 110 bbls class II cuttings, Hauled 210 bbls class II junk fluid to KGF for total of 2055 bbls, Hauled 0 bbls class II cement to KGF for total of 0 bbls. 1/7/20 t5 Trip out F/9023 to the milling assembly (well flowing @ 4bph)L/D mills,starter mill 1/8"under gauge,uooermill full gauge.;Pick up 6"bit,flex jt,5.75"stabilizer, HWDP and jars for the clean out run and with 4 1/2"CDS40 drill pipe from the derrick T/9023'r ill pipe every 3000'. BGG 15 units.;Circulated and condition mud @ 9023'MD. Pump @ 23. .i,w/1220 psi,29%flow,no rotation. Overboarded 57 L oduced water from wellbore while circulating btm's up. Max gas 9876 units.;TIH F/9023 to 9055'(TOW)and set dn 3k. Picked up and slacked back off w/rotary @ 15 rpm,3.7k tq. Saw a slight bobble then passed cleaned,shut rotary off at this time and continued to pass through window with no issues. Work through tight spot @ 9073'and 9091'after setting dn 7k. Picked up and began washing and reaming to btm F/9091'-T/11,000'MD. Pump @ 200 gpm, 1260 psi,40 rpm,5-8k tq. Max gas 8710 units.;Circulate and condition hole @ 11,000'MD. Pump @ 242 gpm,1760 psi,37 rpm,5-7k tq. Pump 25 bbl hi vis sweep w/200%increase in cuttings.;TOH F/11,000'-T/10,650' MD. 180k up,158k dn,165k rot.;Hauled 0 bbls cuttings to KGF for total of 110 bbls, Hauled 280 bbls class II junk fluid to KGF for total of 2335 bbls, Hauled 0 bbls class II cement to KGF for total of 0 bbls. 1/8/2015 Short trip out F/10,900' to the window @ 9077'.180k up,144k dn. Observe the wellbore and trip back to bottom @ 11,000'.Pump Hi/vis sweep cleaning the well bore.Observed sweep across the shakers at the calculated strokes,while circulating the gas peaked @ 9064 units.;Before tripping out to the window weighted up the drilling mud up to 10.8 ppg from 10.6 ppg to help control the water flow.;Trip out of the open hole section pulling the bit above the window.;Spot a 13 ppg pill in the well bore to help hold back the water flow.Well flowing @ 1/2 BB/hr;Trip out laying down 4 1/2"CDS40 drill pipe F/9023'to 6795'to get rid of the excess drill pipe.Continue the trip out standing the needed pipe in the derrick F/6795'to 3486';Cont TOH F/3486'-T/BHA. Stand back HWDP and laydown remaining BHA. Rerun bit grade 3-3-WT-A-E-1-N-TD. #2 cone had rough spot on bearing. Do not re-run SN#3210114 Tricone. Flowcheck 4.3 BPH flow. Total pipe in derrick 134 stds DP,9 stds HWDP;Clean and Clear rig floor. L/D tools and equipment from BHA.;Service rig and topdrive,Check linkage on brakes;PJSM, R/U Weatherford casing and prep for liner run(00:30). PJSM, run 4 1/2",12.6 ppg,L-80,DWC/C-HT casing as per detail.,M/U Shoe track and landing collar,check floats(good),Continue running liner as per detail T/2150'MD. Drifted pups w/3.833"drift prior to running. 59 jts in shed prior to starting job. Tq connections to 6,000 ft/lbs. All centralizers free floating. Total centralizers 28 clamp 5 5/8"centralizers,(10)Rotco 5 11/16"centralizers,(9)Composite spiral 5 5/8"centralizers(across window). Installed liner wiper plug w/1200 psi shear (3 pins)M/U packer,mix and install"pal mix"as per BOT rep.;Hauled 0 cuttings to KGF for total of 110 bbls, Hauled 210 bbls of Class II junk fluid to KGF for total of 2545 bbls. Hauled 0 bbls of Class II cement to KGF for total of 0 bbls. 1/9/2015 Break circulation while rigging down Weatherford power tongs and equipment and change out handling equipment;Trip in with 4 1/2"CDS40 drill pipe from the derrick F/2210'to 9074'filling the drill pipe every 10 stands and circulate a pipe volume @ 7071';Circulate Bottoms up above the window @ 134 gpm,466 psi, max gas @ 9115 units.Work pipe recording parameters before tripping in open hole.;Slack off slow and easy with no pump,at 9053'started taking weight.At 9055'2k had been put on whipstock.Pick up and and bring on pump at 134 gpm,600 psi,slack off and drillstring taking weight at same place(9053')stack 4k and pick up above the whipstock.Continue pumping at 134 gpm with 30 rpm on the topdrive slacking off stacking 5k,off bottom torque is 4600 ft/lbs and started increasing as we stacked weight.Attempting to get through the tight spot on the whipstock,max weight wasl5k with 8k on troque.Called town for instructions,we attempted more weight with different parameters putting up to 20k weight and 12k torque rotating @ 30 rpm.With 12k torque the drillstring backlashed losing 150 psi and 15k in weight.We decided to trip out and have a look.;Circulate while a 20 bbl 13.0ppg weighted cap is mixed.Spot cap and trip out.;TOH F/9055'-T/ surface. Found liner running tool had released off of packer as designed,presumably when trying to pass thru window and string tq'd up then released causing a backlash and left hand tq downhole. This would leave TOF @ 6907'MD. Running tool appeared to be in good condition with no significant damage or scarring. Liner wiper plug came out with running tool(this is good). There was indication that packer might have set when backed off. We did however still have 6 BPH flow after we got out of the hole. This would indicate if packer was set,it was a soft set and shouldn't present any other issues for us.;Clean and clear rig floor. Laydown tools and prep retrieval tool for run. Obtain measurements in shed.;Rig svc;M/U BOT retrieval tool and TIH. Total length LRT=21.82'. 6.2 BPH flow.;CBU @ 6789'MD. Pump @ 211 gpm,805 psi,26%flow. Max gas @ 9625 units. Dumped 35 bbls diluted mud while conditioning mud.;Obtain wts-100k up,100k dn w/pumps. 108k up,108k dn w/out pumps. Continue TIH slowly. Tagged TOF @ 6912'MD. Tagged up 8 times before tool engaged w/8k dn and 1/4 increments to align dogs. P/U 128k(Fish on). 1/10/2015 Trip out with the 4 1/2"liner from 6911'to the casing running tool;Pre job safety with Weatherford casing hands and rig crew,rig up casing equipment and ready the rig floor to lay down 4 1/2"liner;Trip out laying down liner and removing centralizers.100%returns with the jewelry.Wipe the threads and check them for damage Had to heat the collar to break the float sub.The bottom two inches of the float shoe broke off;Rig down the power tongs and clean up the rig floor.Move the mills to the rig floor and strap tools.;Rig svc.;TIH w/packed milling assy to 9018'MD. Stage in hole circulating out gas and produced water. CBU @ 2183' MD,Max gas 4731 units,dumped 35 bbl diluted mud. CBU @ 3739'MD,Max gas 9817 units,dumped 38 bbls diluted mud,CBU @ 5282'MD,Max gas 9880 units,dumped 65 bbls diluted mud. CBU @ 6851'MD,Max gas 7222 units,dumped 78 bbls diluted mud.;Circulate and condition mud @ 9018'MD and wash down to top of whipstock @ 9055'MD. Pump @ 220,1040 psi,25%flow,70 rpm,4.1k tq,146k up,146k dn. 138k rot.;Dress whipstock w/packed milling assy. Tagged up @ 9055'on depth. Begin milling @ 9055',saw(2)eratic tq spikes,peaking @ 12k when intially getting started. Tq leveled out after the first 1'. Observed slight increases in tq several times while working down to our current depth of 9059'MD. Pump @ 220,1040 psi,25%flow,70 rpm,4.1k tq off,146k up,146k dn. 138k rot. 1/11/2015 Continue dressing top of whipstock and face w/BOT milling assy 9055'-9078'MD. Pump @ 220,1040 psi,25%flow,70 rpm,4.1k tq off,146k up,146k dn. 138k rot. Tq stayed consistent @ 4k-7k ft/lbs w/1-3k wob. Tripped thru window twice w/pumps off and twice with pumps on. Tripped clean thru window all 4 times.;Pump high/vis sweep to clean up the wellbore,sweep at shakers and no increase in cuttings.Spotted 20 bbl,13#pill @ 9055'MD. 54 lbs of metal retrieved off the magnets.;Cut and slip 130' of drilling line;Trip out with milling assembly F/9048'-T/surface. Laydown milling assy as per BOT. Starter mill 1/4"under guage,both upper mill showed wear but were guage(6.059"). Flowcheck 2.8 BPH flow.;Clean and clear tools from floor.;Rig svc.;M/U Cleanout assy(620.85')and TIH T/4714'out of derrick. Fill pipe every 25 stds. Flowcheck 2.8 BPH flow while prepping floor to pick up singles from catwalk.;Continue TIH F/4717'-T/6515'MD picking up singles from catwalk. Drift 2.32".;Hauled 0 bbls cutting to KGF for total of 110 bbls, Hauled 280 bbls class II junk fluid to KGF for total of 3035 bbls, Hauled 0 bbls class II cement to KGF for total of 0 bbls. 1/12/2015 Trip in with clean out assembly F/6574'to 9006';Circulate Bottoms up;TIH F/9006'-T/9069',wash and ream dn from 9069'-T/9076'MD. Work cleanout assy @ 9076'attempting to clear obstruction in wellbore(no success). Saw erratic tq(4k-8.5k tq)@ 65 rpm,135 gpm,653 psi. Observed moderate bit bouncing and stalling issues,indicating junk below bit and or around bit. Decision made to pull BHA and inspect. Flowcheck 2.1 BPH flow. 146k UP,146k DN.;Spot 24 bbl, 13#pill @ 9002'MD.;TOH F/9002'-T/surface. Laydown cleanout assy. Found slight scarring on all three cones w/no broken teeth or any other significant markings on BHA. Bit came out a 1/16"under and bearings in good shape.;Clean and clear rig floor.;Service rig;Bring BHI milling tools to rig floor,strap and tally. Flowcheck 4.1 BPH flow.;M/U milling assy(618.33'MD)as per BOT rep and TIH T/2786'MD. Fill pipe every 25 stds.;Hauled 0 bbls of cuttings to KGF for total of 110 bbls,Hauled 70 bbls of class II junk fluid to KGF for total of 3105 bbls, Hauled 0 bbls of class II cement to KGF for total of 0 bbls. 1/13/2015 Trip in with the milling assembly F2786'to 9002';Break circulation and circulate bottoms up with 240 gpm and 1035 psi,Mud weight @ 10.8 ppg.At bottoms up no increase at the shakers and gas topped out at 9861 units.64 bbls of water cut mud was dumped on this circulation.PU/SO 148K,ROT 145K,80 RPM=4.5K torq.;Trip in F/9002'through the whipstock with no pump to 9075',the milling assembly started taking weight.;Break circulation with 240 gpm,80 rpm on the topdrive,4.4k torq,fan bottom with 1k wt.Mill on junk f/9075'3-4k torq to start.With torq diminishing reduce PR to 150 gpm,772 psi and torq increasing to 7-8k. top drive stalled @ 9077.9'with 12k torq.;Metal along side mill.work pipe from f/140k to 180k,pull to 230k,fire jars.Pull to 250k,work torq downhole,release torq.Jar with 100k overpull,4 hits.Pipe came free on upstroke at 220k.;Tag bottom at 9078',continue to mill on junk pumping 240 gpm,1350 psi,80 rpm 4-7k torq.4-5k wob,stalled at 13k-then torq falling off.Continue milling to 9078.5',Pump hi vis sweep,increase pump to 300 gpm,1690 psi.Reduce wob to 4k,small metal shavings at sweep returns.Stall at 9079.7',pull 30k overpull 3 times to free.Reduce to 20 rpm,working passed stall point at 9079',mill to 9080',recovered 2 lbs of metal milling.;Mill from 9080'to 9082.3'pumping 250 gpm, 1433 psi.8-10k wob,95 rpm.6-8k torq.pump hi vis sweep with 3%condet.Increase pump to 308 gpm,1750 psi.No change in pump rate or torq when sweep exited bit.No increase in cuttings.1%cement and 99%very fine sand in returns.;Rack back 1 stand,P/U single.Work from 9050'to 9070'to verify window is clean.Takes wt @ 9066',rotate at 10 rpm,3300 torq,then drops thru window.Repeat 2 more times with the same results.;POH to 9050',Flowcheck,no flow.Spot 20 bbl 13 ppg well cap @ window,well remains static.Blow down top drive.;POH from 9050' to 617'flowcheck well before pulling BHA,well is static,correct fluid displacement on trip out. 1/14/2015 Rack back the HWDP and lay down junk baskets and mills.The mill was wore smooth with no junk damage.The junk baskets were empty.;Clear and clean rig floor,ready the rig floor for trip;Service tf rnd top drive,check brake linkage;Pick up 6"Milltooth I bent joint,trip in filling pipe every 3000'to 9036'.Well • flowing 4.5 bph.;Circulate bottoms up abc. a window,max gas @ 9872 units,dumped 63 bbls wate ,nud.;Wash from 9036'through the whipstock plus 7' pumping 240 gpm to 9075'passing thru window easily.Tag setting down 10k @ 9079'.P/U to 9060',P/U 148K,S/O 148K,rotate pipe 1/4 turn and work torq downhole,set down @ 9070'.P/U to 9060',turn pipe several times 1/4 of turn working torq downhole,slowly losing hole while working pipe @ 9075'.;Establish rotation @ 15 rpm,5-6k torq.lower string slowly looking for hole,tag @ 9074.4'.Cleanout to 9080'stalling topdrive.P/U clean to 9070',continue to rotate and drill up junk from 9079'to 9083'encountering several stalls.At BU recovered 2 lbs consisting of fine metal cuttings with metal shavings.Continue to wash and ream from 9083',pumping 256 gpm,1500 psi,wob 8k,80 rpm,8.5-8.8k torq,pump hi vis sweep.Ream to 9088';Increase wob to 10k,continue to wash and ream from 9088'to 9103',ROP 30-35 fph,no increase in cuttings at sweep returns.Samples show tuffaceous sand.Ream from 9103'with rop decreasing to 5 fph;Wash and ream from 9103'to 9112'pumping 256 gpm,1536 psi.80 rpm,7k torq.WOB 10k,average 5-6 fph,pump hi vis sweeps,no increase in cuttings at sweep returns.;Continue to wash and ream from 9112'to 9135'pumping 256 gpm,1536 psi.80 rpm,7k torq.WOB 10k with rop reducing to 4-5 fph.MW 10.8 ppg. Continue to pump hi vis sweeps every 2 hrs.No increase in cuttings at sweep returns. 1/15/2015 Continue to wash and ream with 6"cleanout assembly from 9135'to 9177'pumping 256 gpm,1570 psi.WOB 10K,80 rpm,7.2k torq.P/U 160K,S/0 160K,ROT 145K.MW 10.8 ppg.No Iosses.;Pump hi vis sweep,20%increase in cuttings @ sweep returns.Flowcheck well,static.Spot 20 bbl 13 ppg well cap.Blow down top drive.;POH with 6"cleanout assembly from 9177'to bit.LID bit and bent jt drill pipe.Bit grade=1/1/WT/A/E/I/NO/BHA.Flowcheck well,well flowing 1/2 bph.;R/U and pull 6 3/8"ID wear ring.Monitor I/A,well is static.;PJSM.R/U test equipment.Install test plug and 4 1/2"test jt.Flood stack and lines with water. Preform BOP body test to 250/3500 psi.no leaks.Monitor I/A;Clean and organize cellar,rig floor and dog house while waiting on AOGCC rep to arrive to witness BOP test.;Test BOPE,Test upper and lower 2 7/8"X 5"VBR,blind ram,choke manifold valves,I/S kill,kill HCR,3rd kill line valve,3"manual valve,HCR,upper and lower IBOP,dart and floor valve to 250/3500 psi 10 minutes each.Perform electric choke and manual choke pressure bleed test.Test annular to 250/2500 psi 10 min ea.Chart all pressure tests.Perform accumulator drawdown test.Function test gas alarm system.AOGCC rep Lou Grimaldi on location to witness test.F/P on 3"manual valve,F/P on rig floor LEL alarm and LEL light due to faulty sensor.;R/D test equipment,close annulas valve.Blow down lines.Install 6 3/8"ID wear bushing. 1/16/2015 PJSM,Cut and slip 202'of drilling line.Reset and test crown-o-matic.Calibrate and test rig smart.Monitor well using trip tank.Well static.;lnspect top drive, draworks brakes,check kick back roller adjustment for brake bands,inspect and torque drive line bolts.;Prep Rig floor for P/U BHA,strap BHA and additional HWDP.P/U 4 jts 4 1/2"HWDP and rack in derrick.;Wait on float sub to srrive.;M/U steerable directional BHA with PDC 6"bit,mud motor with 1.5 deg AKO,DM collar,TM collar,test MWD,pulsing but no detection.;Troubleshoot MWD,L/D DM and TM collars,P/U new DM and TM collars,good test on MWD tools.;Reinstal wear bushing.RI 4 LDS.;M/U Flex collars,12 jts HWDP,X0,jars,XO,13 jts HWDP=916.39';TIH from 916'to 9050',fill pipe every 3000'.Correct displacement on TIH.;PJSM,R/U e-line,m/u side entry sub and Gyro tools with 10'pup above and single below.Clamp e-line. M/U to string,and top drive. Remove clamp.P/U 151K,S/O 151K.;RIH with Gyro,seat gyro 3 times with tool face @ 169 deg,rotate pipe 180 deg.Work torque downhole until tool face is @ 28 deg.Slack off passing thru window easily setting down 5k @ 9075',P/U to 9070';Break circulation,pump 238 gpm,2450 psi.wash to 9084'easily.CBU,5689u gas @ BU.;Shut down pump,POH,park @ 9051'.POH with e-line and gyro for connection.MW 10.8 ppg,well is static 1/17/2015 POH with e-line and gyro for connection.L/D gyro and side entry sub.;TIH from 9050'to 9127',wash and ream to TD @ 9177';M/U side entry sub and gyro,RIH with e-line,P/U and set gyro in UBHO 3 times to ensure set properly,POH form 9120'to 9070'taking surveys every 10'.;Install clamp on side entry sub, CBU.;Remove clamp at side entry sub,POH with e-line,L/D Gyro and side entry sub.;Drill from 9177'to 9207'pumping 230 gpm,1950 psi.WOB 12K,60 rpm,6k torq.P/U 155K,S/0 152K,ROT 153K.MW 10.8 ppg.;Circulate bottoms up.;Park @ 9205',P/U gyro and side entry sub,RIH with e-line and gyro.Seat gyro 3 times to ensure on seat.Gyro survey 2.05 deg inc,274.40 azm.;R/U gyro display screen,Slide drilling using avro to steer from 9207'to 9216'Dumping 238 rim, 2420 psi.WOB 3-6K,3-6 fph.;Continue to slide using gyro to steer from 9216'to 9230'pumping 236 gpm,2415 psi.WOB 5K,3-6 fph.ROP 3 fph.MW 10.8 ppg, no gains,no losses. 1/18/2015 Slide drill 6"hole from 9230'to 9242'using the Gyro for toolfaces;Pull out of the hole with the Gyro and wireline,Break off kelly joint with side entry and lay on beaver slide, make a connection,pick up kelly joint and run in with gyro on wire line;Slide drill from 9242'to 9250',drilling Slow.Gyro survey @ 9194',2.34 inc, 268.16 azm.;POH to 9239'.POH with a-line and gyro,work pipe slowly in 10'increments.L/D gyro tools,side entry sub and pup joint.Flow check,well flowing 7 bph while not pumping.;Drilling from 9250'to 9275'pumping 244 gpm,2080 psi.60 rpm,5.5k torq.WOB 8-12k,P/U 160k,S/O 146K,ROT 150K.ROP 8-15 fph.;Pump mwd survey,3.27 deg inc.Slide drill without gyro from 9275'to 9291'pumping 245 gpm,2300 psi psi. WOB 7-11k.40-75 psi diff.ROP 3-6 fph.MW 10.8 ppg.No losses.No gains. 11.46 slide hrs and 2.23 rotate hrs.7.84'below the line and 16.02'left of the line. 1/19/2015 Slide drilling 6"hole from 9291'to 9326'with 74%sliding time.ROP is slow at 5 ft/hr,rotating at 15 ft/hr.Pumping 247 gpm,with 2300 psi,60 rpm and 5500 ft/lbs torque.;Pull up 2 stands,pick up kelly joint,break out side entry sub and cross overs.Trip back in 2 stands and circulate while rgging down wire line.Max Gas @ 5742 units.Bottoms up,check flow,well flowing @ 9 bbls/hr;Drill Ahead F/9326'to 9363'//PU Wt=162k, Dn Wt=150k, Rt Wt=157k;Drill from 9363'to 9430' pumping 242 gpm,2240 psi.WOB 11-13k.45 rpm,5.6-7.5k torque.Diff 60-120 psi.ROP 11 fph.MW 10.8 PPG.P/U 158k,S/O 150k,ROT 153k.;Drill from 9430' to 9486'pumping 242 gpm,2300 psi.WOB 10-12k.45 rpm,diff 90-140 psi.6-7k torq.ROP 10 fph.Pump hi vis sweep around @ 9400'with 15%increase in cuttings.MW 10.8 ppg,no gains or losses. 15.02 side hrs and 4.31 rotate hrs.Currently 15.01'below the line and 12.48'left of the line. 1/20/2015 Drilling 6"hole from 9486'to 9581',rotating wob 15K,242 gpm-2227 psi,65 rpm-6500 ft/Ibs on bolt torque,8 to 14 ft/hr ROP,MW 10.8 ppg/vis 44,BGG 7 units, well flows at 6 bph during connections,no gain while drilling.ROP was very slow.Discussed with Drilling Engineer and decision made to POOH for bit change.;CBU lx at 242 gpm-2320 psi,66 rpm-5400 ft/lbs off bolt torque.;Pull up hole from 9581'and into casing window to 9044'.Had no issue pulling into window.At 9044'slacked off to exit window and string took weight at 9055'.Picked up 10',made a 1/2 round with drill string,then slacked off and exited window with no problem.Pulled back into casing and parked at 9037'.;Initial flow check at 7 bph.After 15 minutes flow stabilized at 10.5 bph.Pumped and spotted 20 bbls 13 ppg pill to cap well flow.Blew down topdrive.;Cont POOH from 9037'to 6100',flowcheck well,flowing 6 bph.Continue POH from 6100'to HWDP @ 916'. Flowcheck well,flowing 6.6 bph.;POH standing back HWDP,jars,Flex collars.LID UBHO sub.Remove pulser.L/D TM and DM collars,Bit sub.Drain mud motor, L/D and grade bit.2/3/CT/A/X/1/JD/PR.Flow check well,flowing 7 bph.;Monitor well using trip tank,Continues flowing 7 bph.Load tools to rig floor.;PJSM,M/U BHA#15.6"bit,mud motor with 1.5 deg AKO,stab,float sub,DM collar,scribe motor to MWD with offset @ 282.32 deg.M/U RES,TM collar, UBHO,orient same.Download MWD data.M/U 2 NMFC,XO,TIH with 6 stands HWDP to 513',perform MWD shallow hole test.TIH with jars and remaining 13 jts of HWDP from derrick=943.94'Note:well flowing 8 bph while M/U BHA.;TIH from 943'to 2256' 1/21/2015 TIH with BHA#15 from 2256'to 7021',fillina pipe every 2500'.At 7021',gas has increased to 3000 units.:At 7021',MU topdrive and CBU at 3 bpm-270 psi.Had a max of 9137 units and dumped 98 bbls v nd watered back mud.Gas down to less than 100 unite down topdrive.;Cont trip in hole from 7021'to 9048' (just above window).;Fill pipe while RU P, .MU gyro tool and RIH down drill string with e-line.Bit a d',UBHO sub at 8966'.Engaged UBHO sub.1st seat gyro toolface at 320 deg,2nd seat gyro toolface at 318 deg,3rd seat gyro toolface at 318 deg.Turn string 1/8th turn to left and work 15'.Slack off and park at 9047'.1st seat gyro toolface 274 deg,2nd seat gyro toolface 277 deg,3rd seat gyro toolface 279 deg.Window oriented at 280 deg.Pull OOH with e-line.PU single joint,SO and exited window with no problem to 9078'.RD Pollard sheaves and released same.;Well flowing at 20 bph.Cont to trip in 6"open hole from 9078'to 9276'and encountered tight hole.PU and MU topdrive.;Break circ at 163 gpm-1257 psi and cont to circ out water,watered back mud and gas.Cont to circ until good 10.8 ppg in/out.Had a max of 7741 units gas.Dumped a total of 231 bbls water and watered back mud.Hole volume with DP is 319 bbls(depth 9581').;Cont washing/reaming from 9260'to bottom at 9581',208 gpm-1702 psi,40 rpm-4542 ft/lbs off bott torque.;Drill 6"hole from 9581'to 9658'pumping 242 gpm,2035 psi.Diff 20-40 psi.WOB 4-6k,60 rpm,torq 6-6.5k.ROP 17 fph.P/U 150K,S/O 137K,ROT 143K.MW 10.8 ppg,40 vis.Well is flowing 1.5 bph during connections.;Drill from 9658'to 9820'pumping 243 gpm,2080 psi.Diff 30-60 psi.WOB 4-7k,65 RPM,6-7k torq.ROP 23 fph.P/U 162K,S/O 150K,ROT 160K. MW 10.8 ppg,49 vis.BGG 7u.Well is flowing 3.5 bph during connections. Pump hi vis sweep @ 9755',15%increase in cuttings @ sweep returns.;3.87 slide hrs and 2.72 rotate hrs.Currently 0.66'above the line and 2.75'left of the line. Last 24 hrs 210 bbs of junk fluid to KGF,SCU 41 B-04 total 4004 bbls. 1/22/2015 Cont directional drilling 6"hole from 9820'to 9908'.Rotating wob 2 to 3K,243 gpm-2063 psi,60 rpm-7200 ft/lbs on bolt torque,19 to 56 ft/hr ROP.Sliding wob 3 to 8K,256 gpm-2120 psi,85 to 100 psi diff,14 to 55 ft/hr ROP.BGG at 8 units,connection gas 100 to 200 units,MW 10.8 ppg/vis 42,well flows at 4 bph on connections.;At 9908',while sliding,we lost slight pump psi,all diff psi and all bit weight.Started rotating string at 60 rpm and reamed at 64 ft/hr to 9947'with no bit weight,indicating we had entered the original open hole section drilled previously.Worked through transition depth numerous times to ensure good clean transition into original hole.;Gas climbed from 8 units to 7997 units.dropped off,then back up to 9944 units,giving us another indication we had entered the original open hole.Continued to circ out gas.We did not dump any water or light mud,as the lowest MW was a 10.4 ppg.;Cont to wash and ream down from 9947'to 10,260'.242 gpm-2058 psi,60 rpm-5300 to 6900 ft/lbs off bolt torque,at 246 to 500 ft/hr.Took surveys every connection,which pretty much were spot on with the original surveys.Discussed forward op's with Drilling Manager.Decision made to pull up hole,above transition depth of 9908',and work string to ensure transition was good and smooth for liner run.;CBU 1 time at 10,260',241 gpm-1377 psi,with a max of 5769 units gas.Again we did not have to dump any water or light mud overboard.With gas down to 300 units did flow check(8.5 bph)and blew down topdrive.;Pulled up hole from 10,260'to 9849'on elevators.Did have a 20K overpull at 10,175'that we pumped up through(no rotation)after numerous attempts on elevators.Tight spot cleaned right up and cont to pull on elevators remainder of the short trip.;Trip in hole on elevators from 9849'.PU and SO a couple times through the transition depth of 9908'with no issue at all.Notified Drilling Manager and decision made to cont trip in hole.Cont RIH on elevators from 9931'to 10,260'and MU topdrive.;Cont to wash/ream from 10,260'to 11003" at TD,no fill on bottom,pumping 240 gpm-1880 psi,60 rpm-6000-7400 fUlbs off bott torque,taking surveys on each connection.P/U 183K,S/O 160K,ROT 171K. MW 10.8 ppg 53 vis.During connections well flowing 4 bph.;Circulate and cleanup wellbore.Pump 20 bbl hi vis sweep around,242 gpm,2300 psi.Sweep back @ calculated stks.10%increase in cuttings @ sweep returns.Flowcheck well.Flowing 4 bph.;Mad pass log,attempt to pull on elevators pulling up to 240k.. Pump out of hole from from 11003'to 10812 pumping 230 gpm,1800 psi @300 fph making mad pass.Able to pull on elevators from 10812'with no further issues logging 300 fph to 10627'.Blow down top drive.Continue mad pass from 10627'to 9232';;Last 24 hrs 285 bbs of junk fluid to KGF,SCU 41B-04 total 4289 bbls. 1/23/2015 Mad pass log from 9232'to 9109'at 300 ft/hr.At 9109',DM collar(MWD tool)is at bottom of window at 9068'.Check flow rate,4 bph.;Trip in hole on elevators from 9109'to 11,000'.No fill on bottom,no issues at open hole intersection at 9908'.;Break circ at 242 gpm-2199 psi,40 rpm-7800 ft/lbs off bolt torque,pump 20 bbl hi-vis sweep around to clean hole.Had a max of 9574 units gas at bottoms up,dumped 16 bbls watered back mud,sweep back on calculated strokes.+/- 10%increase in cuttings with sweep to surface.Pumped and spotted 20 bbls 300 vis pill outside drillstring.;POOH from 11,000'to 8992'.Had to rotate drill string free on first two stands,then able to pull on elevators remainder of trip.At 10,800'blew down topdrive and flow checked.1.5 bph.Had no issue pulling BHA through open hole intersection at 9908',or pulling BHA through window at 9055'.;Flow check at 8992'is 1.5 bph.Crew changed grabber dies while monitoring well for flow.Pumped and spotted 20 bbls of 13 ppg mud to cap well flow.Blew down topdrive and dropped 2"hollow drift with wire.;POOH from 8992'to 3250', racking back DP in derrick (138 stds).Prep rig floor and cont to POOH laying down excess DP from 3250'to HWDP at 943'.Flow check well,flowing 2.5 bph.;UD jars and XOs,rack 9 stds HWDP in derrick.UD remaining HWDP and flex collars.Upload MWD data.UD UBHO sub,TMC,SP4C,DMC,FS,stab, mud motor and bit.Bit grade=1/2/CT/A/X/I/JD/TD.Flowcheck well,flowing 2 bph.;Clear and clean rig floor.;PJSM,R/U to run 4 1/2"liner.R/U power tongs and handling equipment.Flowcheck well,flowing 4.3 bph.;Service draworks,topdrive,blocks and crown sheaves.;PJSM with rig crew,Tong hand and baker rep.Baker lock and M/U 4 1/2"shoe track(w/bent shoe joint) install centralizer on every joint.Ensure proper operation of float equipment.RIH with 4 1/2"DWC 12.6#liner,install free floating centralizer on every other jt.Use collar clamp on 1st 20 jts.Use optimum torq @ 6000 ft/lbs.Install pup jts with RA tag after jts# 5,7,10 and 15.Fill on the fly and every 10 jts ran.Currently @ 800';;Last 24 hrs 140 bbs of junk fluid to KGF,SCU 41 B-04 total 4429 bbls. 1/24/2015 Qont to PU and RIH with 4 1/2"DWC/C-HT,L-80 12.6 lbs/ft liner from 800'to 2122'.PU and MU Baker 5"x 7"HRD-E ZXPN liner top packer and flex lock liner hanger assembly.Mixed and poured Pal Mix and allowed to set 30 min.RD Weatherford casing tongs and released same.Up wt 28K,down wt 28K.Well flowing at 5 bph.;MU 4 1/2"CDS-40 x 3 1/2"IF XO,MU 1st stand HWDP,MU topdrive,break circ at 140 gpm-226 psi and circulate one full string volume.Blow down topdrive.;Cont RIH with 8 more stands HWDP followed with 4 1/2"DP from 2224'to 8806'.Top filled on the fly and completely filled every 10 stands.At 8806'we picked up Baker cement head and broke off the 15'CDS-40 pup joint on bottom,and MU a full joint of 4 1/2"DP in it's place.LD cement head and staged in"V" door.Cont trip in hole from 8806'to 8990',just above window.;MU topdrive,break circ at 192 gpm-822 psi and performed one full circulation.Had a max of 9810 units gas and dumped 44 bbls watered back mud.Cont circ until good 10.8 ppg in/out.Blew down topdrive.Obtain parameters above window as follows:Up wt 126K,dwn wt 126K,rot wt 127K.Adjust topdrive torque to 10,300 ft/Ibs and at 10 rpm-4200 ft/lbs torque,20 rpm-4300 fUlbs torque,30 rpm-4300 ft/Ibs torque.;Cont ease in hole from 8990',exiting window at 9068'with no problem.Cont trip in hole setting down 5k @ 9738',P/U with 30k overpull,M/U topdrive, break circulation.Pump 142 gpm,530 psi washing past easily.Tag at 9918',P/U 10'and rotate 1 turn to the right,slackoff thru tight spot easily,Tag @ 9970',P/U 10'.M/U topdrive,pump 141 gpm,450 psi,Rotate pipe 1 turn working past 9970'easily.TIH to 10874',wash last 2 stds to 10975';M/U cementing head with single. P/U 158K,S/O 149K.Pump 170 gpm,840 psi.Tag TD @ 11000',Reciprocate pipe in 10'increments.Circulate and condition mud.8046u gas @ BU.Dumped 101 bbls of water cut mud.Mud wt 10.8 ppg in/out.Vis 48.R/U cement lines while circulating.Pipe becoming difficult to reciprocate,50K overpull.Park pipe @ 10998';PJSM with SLB,Baker,DSM,rig crew,peak and mud man.Pump 5 bbls of water.Pressure test lines to 600 psi low and 6000 psi hi 5 min ea.Blow down lines,continue to circulate using rig pump 142 gpm,703 psi.Schlumberger batch mixing cement starting @ 04:20 hrs.;;Last 24 hrs 120 bbs of junk fluid to KGF, SCU 41B-04 total 4549 bbls. 1/25/2015 Rig pumped 25 bbls 12.5 ppg Mud Push II at 3 bpm-562 psi,then blew down topdrive through hardline back to pump.Lined up cement head to SLB.SLB pumped • 92 bb's(d72 cv)a S' ppg f lacc"C;"Fad r.ement at 4 bpm,730 to 200 psi with full returns and s' wn.Baker released dart,then SLB displaced with 10.8 ppg 6%KCL mud at 4 bpm-220 psi ICP. id to 2 bpm with 108 bbls away and saw dart latch wipes 119 bbls into displacement.;lncreased pump rate to 3 bpm-1,100 psi.With 10 bbls to go reduced rate to 2 bpm-1670 psi and bumped plug/landing collar at 151 bbls into displacement.FCP 1720 psi.Held 2620 psi (900 over fcp)for 3 minutes.SLB increased to 3200 psi,we slacked off from 133K to 60K giving us a good indication hanger was set.SLB increased psi to 5,000 psi and held 2 minutes.Bled off 2 bbls back to pump truck and floats held.;PU 6'to clear dogs from hanger top,SO with good indication of shear,PU and had good indication we released liner string.PU,rotated at 10 rpm,SO and set down 65K to set packer.Top of liner hanger at 8842',top of landing collar at 10,869'.6 bbl loss throughout the job,CIP at 08:30 on 1-25-15.;Closed upper rams,lined up on kill line,pressured upon annulus to 1000 psi and held for 10 minutes,good indication liner packer set.Bled off,lined up on topdrive and pressured up to 1,000 psi with rig pump.;PU out of liner hanger with run tool and started pumping as soon as psi started dropping off.Increased pump rate to 6 bpm-1019 psi pumping 10.8 ppg 6%KCL mud.Circulated 1st bottoms up with 25 bbls Mud Push II to surface,and+/-59 bbls cement to surface.LD Baker cement head,inserted wiper ball in drill string and did a 2nd bottoms up at 8 bpm-1391 psi.Blew down topdrive.Racked back one stand DP in derrick.;Hung blocks,cut and slipped 253'drill line.Service rig and topdrive.Calibrate block height and check crown saver.;POOH from 8800'to 554'.PU Baker cement head,break off single,LD same.;Cont POOH rack back HWDP,LD Baker run tool.Rotating dog sub was sheard properly,packoff looked good(still has seals). Operation now goes into"Completion Mode"in wellez;;Last 24 hrs 430 bbs of junk fluid and 59 bbls cement to KGF,SCU 416-04 total 5048 bbls. 1 • Hi!co, =nergy Company Composite ;port Well Name: SCU 41B-04 Field: County/State: ,AK I(LAT/LONG): ?vation(RKB): 18 API#: Spud Date: Job Name: 1413459C SCU 41B-04(SCU 41A-04 ST)COMPLETION Contractor AFE#: 1413459C AFE$: Activity Date Ops Summary 1/25/2015 Pull wear bushing,PU stack wash tool,rinse out stack,function rams and annular.,PJSM,install test plug with 2-7/8"test jt.Fill stack with water.Test upper VBR to 250/3,500 psi 5 min each,test annular to 250/2,500 psi 5 min each.Chart tests.R/D test equipment.Re-install 6-3/8"ID wear bushing.,P/U cement head assembly.Break out XOs and lift sub.L/D same.,Service rig,grease Draworks,blocks and crown sheaves.Inspect draworks brakes and linkage.,PJSM with rig crew,Weatherford hands.R/U Power tongs and 2-7/8"handling equipment.,M/U 3.6875"4 blade bit,bit sub,4-1/2"combo/scraper tool,XO.Drift and P/U 65 jts 2-7/8"PAC tubing and RIH,M/U XO,7"combo/scraper tool,XO,RIH with 9 stds of HWDP.Currently @ 2,400'. 1/26/2015 TIH with 4-1/2"x 7"tandem scraper cleanout assembly,from 2,400'to to 8,782'(just above liner top).MU topdrive.,Perform one full circulation at 287 gpm-1,685 psi and blow down topdrive.,RU test equipment,purge air,test 7"x 4'14"casing at 3,000 psi for 30 minutes on chart.Good test.RD and blow down test equipment.,Resume trip in hole from 8,782'to 10,869'. No issue entering 4 1/"liner top at 8,842'.Stopped at 9,345',9,847'and 10,342'and broke circ.Washed last stand to bottom and tagged top of landing collar at 10,869'.Up wt 158K,down wt 142K in mud.,Displace well to fresh water at 210 gpm-1,624 psi,15 rpm- 4,400 ft/lbs off bott torque in mud,4,900 ft/lbs in water.Blow down topdrive.Off load 280 jnts 3-1/2"tubing,ship out frac tank and two trailer loads mud products to CLU pad.,POOH from 10,869'to upper 7"multiback combo tool(scraper)with bit at 6,481'.Coming off bottom,up wt 174K,down wt 158K in water.,TIH from 6,481'to 10,867'with no issues entering TOL @ 8,842'.,Last 24 hrs 280 bbs of junk fluid to KGF,SCU 41B-04 total 5,259 bbls.,M/U top drive,pump 2nd water displacement pumping 250 gpm,2,300 psi,rotate 15 rpm 4,400#torq,Work pipe.Pump 75 bbl chemical train per mud man consisting of 25 bbl caustic wash followed with 25 bbl bara klean wash then 25 bbl hi vis sweep, Displace well with 3%KCL,dump all returns.Blow down top drive.,POOH L/D drill pipe from 10,867'to 9,119'. 1/27/2015 POOH with 4-1/2"x 7"tandem scraper brush assembly.L/D drill pipe from 9,119'to HWDP at 2,614'.Cont POOH L/D 4-1/2"HWDP and lower multiback combo tool to 2,030'.,C/O handling equipment,RU Weatherford tongs,POOH L/D 2-7/8"workstring,4-1/2"multiback combo tool and XO's,RD 2-7/8"handling equipment.Loaded 2-7/8"on trailer during LD,to send to town with bobtail truck we had in the field.,Pull wear ring,install test plug,RU and test annular and rams with 3-1/2"test joint at 250/2,500 and 250/3,500 psi for 5 minutes each.RD test equipment.,PJSM,PU and MU WLEG,X-Nipple,pup joints,7"hydraulic packer, and chemical injection mandrel. Continue run 3-1/2"completion as per detail. Ran out of stainless steel banding material(Pollard).,Hauled 0 bbls cuttings to KGF for total of 110 bbls,Hauled 830 bbls class II junk fluid to KGF for total of 6,089 bbls,Hauled 0 bbls class II cement to KGF for total of 59 bbls.,Waiting on Pollard to deliver banding material. 1/28/2015 Cont wait on Pollard to deliver SS banding,rig crew serviced rig,cont prep equipment for rig move,cont cleaning pits.,Cont to PU and trip in hole with 3-1/2"8rd, L-80 EUE,9.3#completion tubing 1,407'-8,836'MD. MU 7"x 3-1/2"hanger and landing joint final set depth of 8,836'MD.70k dn,66k up,landed hanger w/60k string wt. RILDS. Install SS band every other joint and 3 per mandrel,to secure chemical injection mandrel control line w/a total of 386 bands.Torqued 8rd connections at 2,500 ft/lbs.,R/U Pollard Wireline-1st run w/20'x 2.5"dummy guns to tag depth of 10,850'MD SLM. 2nd run set RHC profile plug. 3rd run set PX prong.,R/U test pump and chart recorder. Attempt to psi up,fix leak on xo connection. PSI up to 3,500 psi and set packer as per Olgoonik rep. Test tubing T/3,500 psi w/30 min hold(chart and record,test good). R/D test equipment. 1/29/2015 RU test equipment on annulus to test 7"casing and packer.Start bringing up pressure and at 2,400 psi,the landing joint raised up approximately 6".Bled off pressure and hanger dropped back into place.Cameron Reps attempted to tighten lock down studs.Two studs broke off outside of wellhead.Called out additional wellhead Rep with new studs and thread chase tool.,Shipped out gen set#3,mud lab and the three pipeshed modules to next location.,RU Pollard slickline,RIH and retrieved RHCP plug from X-Nipple,POOH,RD Pollard and released same.Peak crane removed centrifuge,removed pit windwalls,hauled off last of stored mud to G&I.Cameron Reps removed old lockdown studs,chased threads and installed three new studs and gland nuts.Fourth stud could not be removed.,RU test equipment on 7"annulus and tested same at 3,000 psi for 30 minutes on chart.Good test.Rd test equipment,LD 3-1/2"EUE landing joint,Cameron installed BPV.,Removed flow line,drip pan,Koomey lines,turnbuckles and mousehole.RU trash pump and whip line to pull 3%KCL from 7"annulus(to freeze protect with diesel).Shipped out Weatherord equipment,Swaco scrapers and excess 3-1/2"tubing. Nipple down BOP stack and prep for move.,Nipple up 11 5k x 7 5k dry hole wellhead as per Cameron Rep.Test upper and lower seals on hanger T/5k w/10 min hold(tests good). Pull BPV install TWC and test tree T/3,500 psi w/5min hold(test good). Pull TWC and secure well.,Freeze protect 3.5"x 7"w/5 gal diesel. Freeze protect 3.5"tbg w/13 gal diesel. Install tree cap and close all valves on wellhead.,Psi wash cellar and wellhead in preparation for turnover to production.,Rig Released @ 06:00 1/30/2015. 1/31/2015 Held pre-job JSA.,NU the 3-1/2"5M Production Tree on top of the Master Valve.Tested tree to 5,000psi,test ok.,Hooked up GL lines and Hung the SSV.Took measurement for the flowline to have it modified.,MIRU Pollard SL Unit over containment.Signed work permits and Held JSA. Pressure tested to 1,000psi-test ok.,RIH w/3"GS w/3-1/2"AD-2 to 4,893'slm,set down in the mandrel,POOH,GS was sheared.,RIH w/3"GS w/3-1/2"AD-2 to 8,800'slm,set AD-2 and POOH.,RIH w/3-1/2"Daniels KOT and 1.25"JDC to 8625'wlm,tool kicked out early and sheared,POOH.,RIH w/same to 8,784'slm,latched and POOH w/dummy. RIH w/same and 1.25"Daniels PT to 8,732'slm,latched and POOH with no dummy,Daniel PT skirt was damaged.,RIH w/same to 8,732'slm,latched POOH with dummy.,RIH w/same to 4,893'slm,set down and could not latch,POOH tool was not sheared.,RIH w/same to 4,893'slm,set down and could not latch, POOH tool was not sheared.,RIH w/3.5"Daniels KOT and 1.25"LIB to 4,893'slm,POOH impression of empty pocket.,RIH w/3.5"KOT and JKRT w/live valve to 4,893 slm,set valve and POOH. RIH w/same and orifice to 8,730'slm,set valve,POOH.,RIH w/same and chem Inj valve to 8,784'slm,set valve and POOH. RIH w/3"GS to 8,800'slm,Pulled AD-2 stop.POOH. Dummy valve was not on top of stop.,RIH w/2.5"gauge ring and tagged bottom at 10,854'slm,POOH. Dummy valve fell to bottom.,RDMO SL.Secured well. 2/2101,5 Held JSA and signed work permit for IoggiP^operation. • MIRU SLB Eline Unit and associated equip it.,MU CBL logging tool w/centralizers.RIH and tagged .n 10,854'.Logged up to top of the liner 8,842'. Cementing looked good. t L. The tool pulled heavy thru the Chem Injection Mandrel and bottom GLM.Had to work logging tool thru the top GLM.POOH and inspected tool and centralizers. Could not find anything wrong with toolstring.,MU PNL tool.RIH to bottom logged up to the TOL and correlated log.RIH back to bottom and logged up to TOL. Data looked good.POOH. RDMO SLB EL Unit. Secured well and SDFN. Will drift with SL before perf. 2/3/2015 Held JSA and signed work permit.MIRU Kauppi SL,RIH w/2.75"GR and tagged bottom at 10,854'slm.POOH. RDMO SL. Unload well with gaslift.,MIRU Pollard SL.Signed permit and JSA.P/T-failed,changed o-ring,test ok,RIH w/3-1/2"Daniels KOT w/1=3/8"JDC to 8,650'KB.Located GLM W/T cant latch POOH/no dummy,RIH w/3-1/2"Daniels KOT w/1-3/8"Daniels PT to 8,622',Latched and span free,POOH wino dummy Droped dummy,Stand by to unload well 2/4/2015 Continued to unload well,RIH w/KOT and dummy valve 8,622'(fliud level 8,620').Set valve and POOH. RIH w/2.75"GR and tag bottom at 10,854',POOH. RDMO SL.,MIRU Priority EL Unit and associated equipment.,RIH w/2.5"x 12'RTG with P/T tool to 10,820'.Logged up to 10,500'and correlated gun on depth. Bled tbg pressure down from 500psi to 130 psi.Fired gun(10,763'-10,775'). POOH. SITP was 900psi.Opened well to sales.,Continued to flow well,MU 2.5"x 20'RTG and gamma/ccl.RIH to 10,800'.Logged up to 10,500',correlated on depth.Fired Bun(10,743'-10,763')and POOH with well flowing. 2.5mcf/d and 400bpd 56%cut.,Continued flowing well,MU 2.5"x 20'RTG and grammy/ccl.RIH to 10,800'.Logged up to 10,500',correlated on depth.Gun would not fire.POOH.SI well at 2,500'so tool would not get blown up hole.Inspected tool and found a short in the firing head.,Re-head gun and RIH w/same. Correlated gun on depth.Opened well and perf from(10,723'-10,743').POOH and stuck the pert guns at 8,743'.Tried to work free while surging well.SI well to min flow rate and tried working free.Continued working and pulled out of the rope socket.POOH.,RDMO EL.,MIRU Pollard 160 SL Unit.and associated equipment.,RIH w/2.75"LIB and tagged TOF at 8,731'SLM.POOH w/image of 1"rope socket. RIH w/1-7/16"OS baited shear-up sub.Engaged fish at report time. 1� L 2/5/2015 Engaged fish at 8,731'SLM.Beat down on fish for 45mins and worked fish down thru the EOT.Continued down hole to 8,900'and set for 30 mins.SITP went from 1,500psi to 1,950psi.,POOH 150 ft/min with fish.,Laid down the pert guns and inspected for damages or the cause for the tools get stuck.Could not find anything wrong with tool. RDMO SL. ! � 4 ` Hilcorp Energy Company CASING&CEMENTING REPORT Lease&Well No. SCU 41B-04 Date 25-Jan-15 County Kenai Peninsula Burough State Alaska Supv. Rance Pederson/Doug Yessak CASING RECORD TD 11003.00 Shoe Depth: 10998.00 PBTD: 10,870'MD/10,716'TVD Casing(Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make Length Bottom Top Shoe 4 1/2 STL Wfd 2.27 10,998.00 _ 10,995.73 2 41/2 12.6 1-80 DWC/C-HT 82.59 10,995.73 10,913.14 F.Collar 41/2 STL Wfd 1.37 10,913.14 10,911.77 1 41/2 12.6 1-80 DWC/C-HT 41.12 10,911.77 10,870.65 Landing collar 41/2 STL Jhobbs 1.03 10,870.65 10,869.62 49 jts 41/2 12.6 _ L-80 DWC/C-HT 1,993.97 10,869.62 8,875.65 LH/PKR 33.31 8,875.65 8,842.34 Totals 2,160.21 Csg Wt.On Hook: 44,812 Type Float Collar: Model 303E No.Hrs to Run: 23 Csg Wt.On Slips: Type of Shoe: Reamer shoe Casing Crew: WFD Fluid Description: 10.8 ppg Kla-shield mud/PV=12 YP=17 HTHP=14.9 Liner hanger Info(Make/Model): HRD-E ZXPN PKR- Flex-Lock Liner Hanger Liner top Packer?: X Yes_No Liner hanger test pressure: 1000 Centralizer Placement: Centralizers on each joint in shoe track,and every other joint in csg string Total of 28 centralizers ran CEMENTING REPORT Preflush(Spacer) Type: Mud Push II Density(ppg) 12.5 Volume pumped(BBLs) 25 Lead Slurry `1/41".�4 Type: EZBLOK 4 Density(ppg) 15.3 Volume pumped(BBLs) 92 Mixing/Pumping Rate(bpm): 4 Tall Slurry Type: l Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm): y Post Flush(Spacer) N Type: Density(ppg) Rate(bpm): Volume: 0 IT Displacement: Type: Kla-shield mud Density(ppg) 10.8 Rate(bpm): 4 bpm Volume(actual/calculated): 151/151 FCP(psi): 1720 Pump used for disp: Schlumberger pump Plug Bumped? X Yes No Bump press 2620 Casing Rotated? Yes X No Reciprocated? Yes X No %Returns during job 100 Cement returns to surface? X Yes_No Spacer returns? X Yes_No Vol to Surf: 25 bbls mud push/59 bbls cmt Cement In Place At: 8:30 Date: 1/25/2015 Estimated TOC: 8,870 Method Used To Determine TOC: Cement returns circulating TOL after packer set. 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): N Post Flush(Spacer) 0 o Type: Density(ppg) Rate(bpm): Volume: C.) 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 during job 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: WELLHEAD Make Type Serial No. Size W.P. Test Head To PSIG MIN OK Remarks: I 11 i , Hilcorp Energy Company Soldotna CK Unit Soldotna CK Unit SCU 41B-04 501331010903 501331010903 c Sperry Drilling Definitive Survey Report ort 09 February, 2015 r 1111 HALLIBURTON Sperry Drilling 1 • Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Soldotna CK Unit 341-04 • Project: Soldotna CK Unit TVD Reference: SCU 41B-04 @ 191.70usft(Saxon 169(173.7'GL+18'F • Site: Soldotna CK Unit MD Reference: SCU 41B-04 @ 191.70usft(Saxon 169(173.7'GL+18'F Well: Soldotna CK Unit 341-04 North Reference: True Wellbore: SCU 41B-04 Survey Calculation Method: Minimum Curvature " Design: SCU 41B-04 Database: Sperry EDM-NORTH US+CANADA Project Soldotna CK Unit,Swanson River Field 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 Well Soldotna CK Unit 341-04 Well Position +N/-S 0.00 usft Northing: 2,460,223,81 usft - Latitude: 60°43'52.634 N +E/-W 0.00 usft Easting: 346,506.27 usft • Longitude: 150°51'27.010 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: . 173.70 usft Wellbore SCU 41B-04 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2014 12/15/2014 16.92 73.71 55,471 Design SCU 41B-04 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 9,004.70 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 18.00 0.00 0.00 8.93 Survey Program Date 2/9/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 104.70 9,004.70 SCU 42-04[GyroData Continuous Gyro] NSG-CT_WL Continuous north-seeking gyro on wireline 08/04/2014 9,055.00 9,141.00 SCU 41B-04 NSG-CT_D/P(SCU 41B-04 NSG-CT_D/P Continuous north-seeking gyro in drillpipe 01/18/2015 9,169.23 10,960.69 SCU 41B-04 MWD+SC+sag(SCU 41B-0 MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 01/18/2015 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 18.00 0.00 0.00 18.00 -173.70 0.00 0.00 2,460,223.81 346,506.27 0.00 0.00 UNDEFINED 104.70 0.42 354.38 104.70 -87.00 0.32 -0.03 2,460,224.13 346,506.24 0.48 0.31 NSG-CT_WL(1) 204.70 0.40 2.48 204.70 13.00 1.03 -0.05 2,460,224.84 346,506.23 0.06 1.01 NSG-CT_WL(1) 304.70 0.40 354.88 304.69 112.99 1.73 -0.07 2,460,225.54 346,506.23 0.05 1.69 NSG-CT_WL(1) 404.70 0.53 317.28 404.69 212.99 2.41 -0.41 2,460,226.23 346,505.89 0.32 2.32 NSG-CT_WL(1) 504.70 0.68 319.51 504.69 312.99 3.20 -1.11 2,460,227.03 346,505.20 0.15 2.99 NSG-CT_WL(1) 604.70 0.83 321.30 604.68 412.98 4.22 -1.95 2,460,228.06 346,504.38 0.15 3.87 NSG-CT_WL(1) 704.70 0.83 322.25 704.67 512.97 5.36 -2.85 2,460,229.21 346,503.49 0.01 4.85 NSG-CT_WL(1) 804.70 0.74 322.63 804.66 612.96 6.45 -3.68 2,460,230.31 346,502.67 0.09 5.80 NSG-CT_WL(1) 904.70 0.58 329.07 904.65 712.95 7.39 -4.33 2,460,231.26 346,502.03 0.18 6.63 NSG-CT_WL(1) 1,004.70 0.50 334.88 1,004.65 812.95 8.22 -4.78 2,460,232.10 346,501.60 0.10 7.38 NSG-CT_WL(1) 1,104.70 0.39 331.59 1,104.64 912.94 8.92 -5.13 2,460,232.80 346,501.26 0.11 8.01 NSG-CT_WL(1) 2/9/2015 1:52:49PM Page 2 COMPASS 5000.1 Build 73 Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Soldotna CK Unit 341-04 Project: Soldotna CK Unit TVD Reference: SCU 41B-04 @ 191.70usft(Saxon 169(173.7'GL+18'F Site: Soldotna CK Unit MD Reference: SCU 41 B-04 @ 191.70usft(Saxon 169(173.7'GL+18'1 Well: Soldotna CK Unit 341-04 North Reference: True Wellbore: SCU 41B-04 Survey Calculation Method: Minimum Curvature Design: SCU 41B-04 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) 0100') (ft) Survey Tool Name 1,204.70 0.28 342.23 1,204.64 1,012.94 9.45 -5.36 2,460,233.33 346,501.03 0.13 8.50 NSG-CT_WL(1) 1,304.70 0.04 127.28 1,304.64 1,112.94 9.66 -5.41 2,460,233.54 346,500.99 0.31 8.70 NSG-CT_WL(1) 1,404.70 0.16 128.63 1,404.64 1,212.94 9.55 -5.27 2,460,233.43 346,501.12 0.12 8.62 NSG-CT_WL(1) 1,504.70 0.50 99.75 1,504.64 1,312.94 9.39 -4.73 2,460,233.27 346,501.66 0.37 8.54 NSG-CT WL(1) 1,604.70 0.41 97.05 1,604.64 1,412.94 9.27 -3.95 2,460,233.14 346,502.44 0.09 8.55 NSG-CT WL(1) 1,704.70 0.39 98.05 1,704.63 1,512.93 9.18 -3.26 2,460,233.04 346,503.13 0.02 8.56 NSG-CT_WL(1) 1,804.70 0.23 126.82 1,804.63 1,612.93 9.01 -2.76 2,460,232.86 346,503.63 0.22 8.48 NSG-CT_1ML(1) 1,904.70 0.23 144.75 1,904.63 1,712.93 8.73 -2.48 2,460,232.57 346,503.90 0.07 8.24 NSG-CT_1NL(1) 2,004.70 0.21 137.87 2,004.63 1,812.93 8.43 -2.24 2,460,232.27 346,504.14 0.03 7.98 NSG-CT_WL(1) 2,104.70 0.24 142.59 2,104.63 1,912.93 8.13 -1.99 2,460,231.97 346,504.38 0.04 7.72 NSG-CT_WL(1) 2,204.70 0.51 138.97 2,204.63 2,012.93 7.62 -1.57 2,460,231.46 346,504.80 0.27 7.29 NSG-CT WL(1) 2,304.70 0.57 138.26 2,304.62 2,112.92 6.92 -0.95 2,460,230.74 346,505.41 0.06 6.69 NSG-CT WL(1) 2,404.70 0.57 134.87 2,404.62 2,212.92 6.20 -0.27 2,460,230.01 346,506.08 0.03 6.08 NSG-CT_WL(1) 2,504.70 0.49 137.70 2,504.61 2,312.91 5.53 0.37 2,460,229.34 346,506.72 0.08 5.52 NSG-CT_WL(1) 2,604.70 0.60 137.21 2,604.61 2,412.91 4.83 1.02 2,460,228.63 346,507.35 0.11 4.93 NSG-CT_WL(1) 2,704.70 0.62 133.61 2,704.60 2,512.90 4.07 1.76 2,460,227.86 346,508.09 0.04 4.29 NSG-CT_WL(1) 2,804.70 0.54 140.03 2,804.60 2,612.90 3.34 2.46 2,460,227.12 346,508.77 0.10 3.68 NSG-CT_WL(1) 2,904.70 0.53 141.33 2,904.59 2,712.89 2.61 3.05 2,460,226.39 346,509.36 0.02 3.06 NSG-CT WL(1) 3,004.70 0.29 148.80 3,004.59 2,812.89 2.04 3.47 2,460,225.80 346,509.77 0.25 2.55 NSG-CT_WL(1) 3,104.70 0.19 158.65 3,104.59 2,912.89 1.67 3.66 2,460,225.43 346,509.95 0.11 2.21 NSG-CT_WL(1) 3,204.70 0.20 176.18 3,204.59 3,012.89 1.34 3.73 2,460,225.10 346,510.02 0.06 1.90 NSG-CT_WL(1) 3,304.70 0.17 137.06 3,304.59 3,112.89 1.05 3.85 2,460,224.82 346,510.13 0.13 1.64 NSG-CT_WL(1) 3,404.70 0.10 131.80 3,404.59 3,212.89 0.89 4.01 2,460,224.65 346,510.29 0.07 1.50 NSG-CT WL(1) 3,504.70 0.03 134.10 3,504.59 3,312.89 0.81 4.10 2,460,224.57 346,510.38 0.07 1.44 NSG-CT WL(1) 3,604.70 0.21 140.51 3,604.59 3,412.89 0.65 4.23 2,460,224.41 346,510.51 0.18 1.30 NSG-CT WL(1) 3,704.70 0.05 122.07 3,704.59 3,512.89 0.49 4.39 2,460,224.24 346,510.66 0.16 1.16 NSG-CT WL(1) 3,804.70 0.56 193.26 3,804.59 3,812.89 -0.01 4.31 2,460,223.75 348,510.58 0.55 0.66 NSG-CT_WL(1) 3,904.70 0.58 195.47 3,904.58 3,712.88 -0.98 4.06 2,460,222.79 346,510.32 0.03 -0.33 NSG-CT WL(1) 4,004.70 0.64 180.30 4,004.58 3,812.88 -2.02 3.93 2,460,221.74 346,510.17 0.17 -1.39 NSG-CT WL(1) 4,104.70 1.01 165.28 4,104.57 3,912.87 -3.43 4.15 2,460,220.33 346,510.37 0.43 -2.75 NSG-CT_WL(1) 4,204.70 1.17 166.24 4,204.55 4,012.85 -5.28 4.61 2,460,218.48 346,510.81 0.16 -4.50 NSG-CT_WL(1) 4,304.70 0.84 177.49 4,304.53 4,112.83 -7.00 4.89 2,460,216.75 346,511.07 0.38 -6.16 NSG-CT_WL(1) 4,404.70 0.68 195.40 4,404.52 4,212.82 -8.31 4.76 2,460,215.45 346,510.92 0.28 -7.47 NSG-CT_WL(1) 4,504.70 0.52 184.54 4,504.52 4,312.82 -9.33 4.57 2,460,214.43 346,510.72 0.20 -8.51 NSG-CT WL(1) 4,604.70 0.40 188.10 4,604.51 4,412.81 -10.13 4.48 2,460,213.63 346,510.62 0.12 -9.31 NSG-CT_WL(1) 4,704.70 0.19 190.02 4,704.51 4,512.81 -10.64 4.41 2,460,213.12 346,510.54 0.21 -9.82 NSG-CT WL(1) 4,804.70 0.11 151.84 4,804.51 4,612.81 -10.88 4.42 2,460,212.87 346,510.55 0.12 -10.07 NSG-CT_WL(1) 4,904.70 0.23 205.00 4,904.51 4,712.81 -11.15 4.38 2,460,212.61 346,510.51 0.19 -10.34 NSG-CT_WL(1) 5,004.70 0.60 245.96 5,004.51 4,812.81 -11.55 3.82 2,460,212.22 346,509.94 0.45 -10.81 NSG-CT WL(1) 5,104.70 1.04 278.53 5,104.50 4,912.80 -11.62 2.44 2,460,212.16 346,508.56 0.62 -11.10 NSG-CT WL(1) 2/9/2015 1:52.49PM Page 3 COMPASS 5000.1 Build 73 Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Soldotna CK Unit 341-04 Project: Soldotna CK Unit TVD Reference: SCU 41B-04 @ 191.70usft(Saxon 169(173.7'GL+18'F Site: Soldotna CK Unit MD Reference: SCU 41B-04 @ 191.70usft(Saxon 169(173.7'GL+18'I Well: Soldotna CK Unit 341-04 North Reference: True Wellbore: SCU 41B-04 Survey Calculation Method: Minimum Curvature Design: SCU 41B-04 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) 0100') (ft) Survey Tool Name 5,204.70 1.21 291.14 5,204.48 5,012.78 -11.11 0.56 2,460,212.70 346,506.69 0.30 -10.89 NSG-CT_WL(1) 5,304.70 1.16 305.96 5,304.46 5,112.76 -10.13 -1.24 2,480,213.70 346,504.90 0.31 -10.20 NSG-CT_WL(1) 5,404.70 0.95 318.90 5,404.44 5,212.74 -8.92 -2.61 2,460,214.93 346,503.55 0.32 -9.21 NSG-CT_WL(1) 5,504.70 0.96 314.00 5,504.43 5,312.73 -7.71 -3.75 2,460,216.16 346,502.42 0.08 -8.20 NSG-CT_WL(1) 5,604.70 0.91 310.95 5,604.42 5,412.72 -6.61 -4.96 2,460,217.27 346,501.23 0.07 -7.30 NSG-CT_WL(1) 5,704.70 0.32 299.34 5,704.41 5,512.71 -5.95 -5.80 2,460,217.94 346,500.39 0.60 -6.78 NSG-CT_WL(1) 5,804.70 0.61 309.69 5,804.41 5,612.71 -5.47 -6.45 2,460,218.43 346,499.75 0.30 -6.41 NSG-CT_WL(1) 5,904.70 0.60 301.39 5,904.40 5,712.70 -4.86 -7.31 2,460,219.05 346,498.90 0.09 -5.94 NSG-CT_WL(1) 6,004.70 0.26 305.74 6,004.40 5,812.70 -4.45 -7.94 2,460,219.46 346,498.27 0.34 -5.63 NSG-CT_WL(1) 6,104.70 0.11 291.88 6,104.40 5,912.70 -4.29 -8.21 2,460,219.64 346,498.00 0.16 -5.51 NSG-CT WL(1) 6,204.70 0.34 310.18 6,204.40 6,012.70 -4.06 -8.53 2,460,219.87 346,497.69 0.24 -5.33 NSG-CT WL(1) 6,304.70 0.16 184.10 6,304.40 6,112.70 -4.01 -8.77 2,460,219.92 346,497.45 0.45 -5.32 NSG-CT WL(1) 6,404.70 0.26 248.99 6,404.40 6,212.70 -4.23 -8.99 2,460,219.70 346,497.23 0.24 -5.57 NSG-CT_WL(1) 6,504.70 0.18 270.69 6,504.39 6,312.69 -4.31 -9.36 2,460,219.63 346,496.86 0.11 -5.71 NSG-CT_WL(1) 6,604.70 0.15 279.65 6,604.39 6,412.69 -4.28 -9.64 2,460,219.66 346,496.57 0.04 -5.73 NSG-CT WL(1) 6,704.70 0.17 257.68 6,704.39 6,512.69 -4.29 -9.92 2,460,219.65 346,496.30 0.06 -5.78 NSG-CT WL(1) 6,804.70 0.19 250.91 6,804.39 6,612.69 -4.38 -10.22 2,460,219.57 346,496.00 0.03 -5.91 NSG-CT WL(1) 6,904.70 0.29 290.15 6,904.39 6,712.69 -4.35 -10.61 2,460,219.61 346,495.60 0.19 -5.94 NSG-CT WL(1) 7,004.70 0.26 318.35 7,004.39 6,812.69 -4.09 -11.00 2,460,219.87 346,495.22 0.14 -5.75 NSG-CT WL(1) 7,104.70 0.23 344.80 7,104.39 6,912.69 -3.73 -11.20 2,460,220.24 346,495.02 0.12 -5.42 NSG-CT WL(1) 7,204.70 0.25 24.48 7,204.39 7,012.69 -3.33 -11.17 2,460,220.63 346,495.06 0.16 -5.03 NSG-CT_W1 (1) 7,304.70 0.57 55.39 7,304.39 7,112.69 -2.85 -10.67 2,460,221.10 346,495.57 0.38 -4.47 NSG-CT_WL(1) 7,404.70 0.96 86.02 7,404.38 7,212.68 -2.51 -9.42 2,460,221.43 346,496.82 0.55 -3.94 NSG-CT_WL(1) 7,504.70 1.30 97.37 7,504.36 7,312.66 -2.60 -7.46 2,460,221.31 346,498.78 0.41 -3.73 NSG-CT_WL(1) 7,604.70 1.41 106.20 7,604.33 7,412.63 -3.09 -5.15 2,460,220.79 346,501.08 0.24 -3.85 NSG-CT_WL(1) 7,704.70 1.15 114.35 7,704.31 7,512.61 -3.84 -3.06 2,460,220.01 346,503.16 0.32 -4.27 NSG-CT_WL(1) 7,804.70 1.05 121.12 7,804.29 7,612.59 -4.73 -1.36 2,460,219.10 346,504.85 0.16 -4.89 NSG-CT_WL(1) 7,904.70 1.12 122.79 7,904.27 7,712.57 -5.73 0.25 2,460,218.08 346,506.44 0.08 -5.63 NSG-CT WL(1) 8,004.70 1.11 121.32 8,004.25 7,812.55 -6.77 1.89 2,460,217.02 346,508.08 0.03 -6.39 NSG-CT WL(1) 8,104.70 0.89 128.03 8,104.24 7,912.54 -7.75 3.33 2,460,216.02 346,509.50 0.25 -7.14 NSG-CT_WL(1) 8,204.70 0.72 121.44 8,204.23 8,012.53 -8.56 4.48 2,460,215.20 346,510.64 0.19 -7.76 NSG-CT WL(1) 8,304.70 0.70 125.15 8,304.22 8,112.52 -9.23 5.52 2,460,214.51 346,511.67 0.05 -8.27 NSG-CT WL(1) 8,404.70 0.37 133.94 8,404.21 8,212.51 -9.81 6.25 2,460,213.92 346,512.39 0.34 -8.72 NSG-CT_WL(1) 8,504.70 0.43 131.45 8,504.21 8,312.51 -10.28 6.76 2,460,213.44 346,512.90 0.06 -9.11 NSG-CT WL(1) 8,604.70 0.45 128.90 8,604.21 8,412.51 -10.78 7.35 2,460,212.94 346,513.48 0.03 -9.51 NSG-CT_WL(1) 8,704.70 0.38 135.87 8,704.21 8,512.51 -11.26 7.89 2,460,212.45 346,514.01 0.09 -9.90 NSG-CT WL(1) 8,804.70 0.21 112.29 8,804.20 8,612.50 -11.57 8.29 2,460,212.14 346,514.41 0.21 -10.14 NSG-CT_WL(1) 8,904.70 0.21 325.39 8,904.20 8,712.50 -11.49 8.35 2,460,212.22 346,514.47 0.40 -10.05 NSG-CT_WL(1) 9,004.70 0.32 354.87 9,004.20 8,812.50 -11.06 8.22 2,460,212.65 346,514.35 0.17 -9.65 NSG-CT_WL(1) 9,055.00 0.28 348.71 9,054.50 8,862.80 -10.80 8.19 2,460,212.91 346,514.32 0.10 -9.40 NSG-CT_D/P(2) 2/9/2015 1:52:49PM Page 4 COMPASS 5000.1 Build 73 Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Soldotna CK Unit 341-04 Project: Soldotna CK Unit TVD Reference: SCU 41B-04 @ 191.70usft(Saxon 169(173.7'GL+18'1 Site: Soldotna CK Unit MD Reference: SCU 416-04 @ 191.70usft(Saxon 169(173.7'GL+18'I Well: Soldotna CK Unit 341-04 North Reference: True Wellbore: SCU 41B-04 Survey Calculation Method: Minimum Curvature Design: SCU 41B-04 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 9,068.00 1.52 288.12 9,067.50 8,875.80 -10.71 8.02 2,460,213.00 346,514.15 10.80 -9.34 NSG-CT_D/P(2) 9,080.00 2.10 278.88 9,079.49 8,887.79 -10.63 7.65 2,460,213.08 346,513.78 5.40 -9.32 NSG-CT_D/P(2) 9,090.00 2.13 275.63 9,089.49 8,897.79 -10.58 7.28 2,460,213.13 346,513.41 1.24 -9.33 NSG-CT_D/P(2) 9,100.00 2.40 272.54 9,099.48 8,907.78 -10.56 6.89 2,460,213.17 346,513.02 2.96 -9.36 NSG-CT D/P(2) 9,110.00 2.32 273.56 9,109.47 8,917.77 -10.54 6.48 2,460,213.19 346,512.61 0.90 -9.40 NSG-CT_D/P(2) 9,121.00 2.29 270.79 9,120.46 8,928.76 -10.52 6.03 2,460,213.22 346,512.17 1.05 -9.45 NSG-CT_D/P(2) 9,194.00 2.34 268.16 9,193.40 9,001.70 -10.55 3.09 2,460,213.23 346,509.22 0.16 -9.94 MWD+SC+sag(3) 9,247.14 3.50 340.80 9,246.49 9,054.79 -9.05 1.47 2,460,214.75 346,507.62 6.74 -8.71 MWD+SC+sag(3) 9,293.57 6.46 357.48 9,292.74 9,101.04 -5.10 0.89 2,460,218.70 346,507.09 7.03 -4.90 MWD+SC+sag(3) 9,323.56 9.10 7.75 9,322.45 9,130.75 -1.06 1.13 2,460,222.74 346,507.39 9.92 -0.87 MWD+SC+sag(3) 9,355.94 11.50 16.61 9,354.31 9,162.61 4.57 2.40 2,460,228.35 346,508.73 8.86 4.89 MWD+SC+sag(3) 9,386.23 13.86 21.49 9,383.86 9,192.16 10.84 4.59 2,460,234.59 346,511.01 8.55 11.42 MWD+SC+sag(3) 9,448.35 15.63 28.88 9,443.94 9,252.24 25.09 11.36 2,460,248.75 346,517.96 4.15 26.55 MWD+SC+sag(3) 9,481.23 15.68 30.71 9,475.60 9,283.90 32.79 15.77 2,460,256.40 346,522.47 1.51 34.84 MWD+SC+sag(3) 9,509.14 16.35 33.42 9,502.43 9,310.73 39.31 19.86 2,460,262.86 346,526.64 3.60 41.92 MWD+SC+sag(3) 9,541.48 16.66 32.34 9,533.43 9,341.73 47.03 24.85 2,460,270.51 346,531.73 1.35 50.31 MWD+SC+sag(3) 9,596.36 17.31 31.39 9,585.92 9,394.22 60.64 33.31 2,460,284.02 346,540.37 1.29 65.08 MWD+SC+sag(3) 9,658.73 16.83 23.39 9,645.55 9,453.85 76.85 41.73 2,460,300.12 346,549.00 3.84 82.40 MWD+SC+sag(3) 9,719.72 16.96 12.58 9,703.92 9,512.22 93.64 47.17 2,460,316.83 346,554.66 5.15 99.83 MWD+SC+sag(3) 9,752.35 17.13 5.25 9,735.12 9,543.42 103.08 48.65 2,460,326.25 346,556.26 6.60 109.38 MWD+SC+sag(3) 9,783.32 16.56 359.06 9,764.77 9,573.07 112.03 48.99 2,460,335.20 346,556.72 6.07 118.28 MWD+SC+sag(3) 9,846.16 14.73 3.99 9,825.28 9,633.58 128.96 49.40 2,460,352.11 346,557.35 3.60 135.06 MWD+SC+gag(3) 9,907.05 16.76 6.14 9,883.88 9,692.18 145.41 50.88 2,460,368.55 346,559.04 3.47 151.55 MWD+SC+sag(3) 9,968.73 21.65 1.47 9,942.11 9,750.41 165.64 52.12 2,460,388.76 346,560.55 8.30 171.72 MWD+SC+sag(3) 10,031.16 23.95 0.95 9,999.66 9,807.96 189.83 52.63 2,460,412.94 346,561.37 3.70 195.69 MWD+SC+sag(3) 10,092.51 24.67 1.95 10,055.57 9,863.87 215.07 53.27 2,460,438.17 346,562.35 1.35 220.73 MWD+SC+sag(3) 10,155.18 26.41 2.72 10,112.12 9,920.42 242.07 54.38 2,460,465.15 346,563.80 2.83 247.57 MWD+SC+sag(3) 10,216.86 29.36 3.87 10,166.63 9,974.93 270.86 56.05 2,460,493.92 346,565.85 4.86 276.28 MWD+SC+sag(3) 10,279.61 30.92 4.96 10,220.89 10,029.19 302.27 58.48 2,460,525.30 346,568.69 2.63 307.69 MWD+SC+sag(3) 10,341.39 33.95 5.38 10,273.03 10,081.33 335.27 81.47 2,460,558.25 346,572.12 4.92 340.75 MWD+SC+sag(3) 10,355.87 33.93 5.60 10,285.04 10,093.34 343.32 62.25 2,460,566.29 346,572.99 0.86 348.82 MWD+SC+sag(3) 10,402.26 34.16 5.62 10,323.48 10,131.78 369.16 64.78 2,460,592.10 346,575.87 0.50 374.75 MWD+SC+sag(3) 10,463.03 34.03 5.38 10,373.81 10,182.11 403.07 68.05 2,460,625.96 346,579.58 0.31 408.75 MWD+SC+sag(3) 10,527.73 33.58 5.13 10,427.57 10,235.87 438.92 71.35 2,460,661.76 346,583.34 0.73 444.67 MWD+SC+sag(3) 10,589.84 33.12 4.88 10,479.45 10,287.75 472.93 74.33 2,460,695.74 346,586.77 0.77 478.74 MWD+SC+sag(3) 10,649.72 32.56 4.67 10,529.76 10,338.06 505.29 77.03 2,460,728.06 346,589.89 0.95 511.12 MWD+SC+sag(3) 10,713.27 32.22 4.11 10,583.42 10,391.72 539.23 79.64 2,460,761.96 346,592.94 0.71 545.06 MWD+SC+sag(3) 10,774.35 32.13 3.35 10,635.12 10,443.42 571.69 81.75 2,460,794.39 346,595.48 0.68 577.45 MWD+SC+sag(3) 10,837.26 32.10 2.30 10,688.41 10,496.71 605.09 83.40 2,460,827.77 346,597.57 0.89 610.70 MWD+SC+gag(3) 10,899.26 31.88 1.53 10,740.99 10,549.29 637.92 84.50 2,460,860.58 346,599.09 0.75 643.30 MWD+SC+sag(3) 2/9/2015 1:52:49PM Page 5 COMPASS 5000.1 Build 73 • Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Soldotna CK Unit 341-04 Project: Soldotna CK Unit TVD Reference: SCU 41B-04 @ 191.70usft(Saxon 169(173.7'GL+18'F Site: Soldotna CK Unit MD Reference: SCU 41B-04 @ 191.70usft(Saxon 169(173.7'GL+18'F Well: Soldotna CK Unit 341-04 North Reference: True Wellbore: SCU 41B-04 Survey Calculation Method: Minimum Curvature Design: SCU 41B-04 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 10,960.69 31.80 0.80 10,793.18 10,601.48 670.32 85.16 2,460,892.97 346,600.17 0.64 675.41 MWD+SC+sag(3) 11,003.00 31.80 0.80 10,829.14, 10,637.44 692.61 85.47 2,460,915.25 346,600.78 0.00 697.49 PROJECTED to TD Checked By: Patrick Walker .:.� :. .-. Approved By: Cary Taylor °m,7,,s,,,� A Date: 2/9/2015 1:52:49PM Page 6 COMPASS 5000.1 Build 73 Hilcorp Energy Company Soldotna CK Unit Soldotna CK Unit 111 SCU 41 B-04PB1 501331010970 501331010970 Sperry Drilling Definitive Survey Report A 09 February, 2015 HALL IBURTON Sperry Drilling � �r Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Soldotna CK Unit 341-04 Project: Soldotna CK Unit TVD Reference: SCU 41B-04 @ 191.70usft(Saxon 169(173.7'GL+18'i Site: Soldotna CK Unit MD Reference: SCU 41B-04 @ 191.70usft(Saxon 169(173.7'GL+18'F Well: Soldotna CK Unit 341-04 North Reference: True Wellbore: SCU 41B-04PB1 Survey Calculation Method: Minimum Curvature Design: SCU 41 B-04PB1 Database: Sperry EDM-NORTH US+CANADA Project Soldotna CK Unit,Swanson River Field 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 Well Soldotna CK Unit 341-04 Well Position +N/-S 0.00 usft Northing: 2,460,223.81 usft Latitude: 60°43'52.634 N +E/-W 0.00 usft Easting: 346,506.27 usft Longitude: 150°51'27.010 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 173.70 usft Wellbore SCU 41 B-04PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2014 12/15/2014 16.92 73.71 55,471 Design SCU 41 B-04PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 9,004.70 Vertical Section: Depth From(TVD) +N/-S +El-W Direction (usft) (usft) (usft) (°) 18.00 0.00 0.00 8.93 Survey Program Date 2/9/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 104.70 9,004.70 SCU 42-04[GyroData Continuous Gyro] NSG-CT_WL Continuous north-seeking gyro on wireline 08/04/2014 9,055.00 9,392.50 SCU 41B-04 MWD_Interp Azi+Sag(SCU MWD_Interp Azi+sag Fixed:v2:std dec with interpolated azimuth+sag 12/25/2014 9,488.78 9,858.69 SCU 41B-04 MWD+SC+sag(SCU 41B-0 MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 12/30/2014 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) " (ft) (°/100') (ft) Survey Tool Name 18.00 0.00 0.00 18.00 -173.70 0.00 0.00 2,460,223.81 346,506.27 0.00 0.00 UNDEFINED 104.70 0.42 354.38 104.70 -87.00 0.32 -0.03 2,460,224.13 346,506.24 0.48 0.31 NSG-CT_WL(1) 204.70 0.40 2.48 204.70 13.00 1.03 -0.05 2,460,224.84 346,506.23 0.06 1.01 NSG-CT_WL(1) 304.70 0.40 354.88 304.69 112.99 1.73 -0.07 2,460,225.54 346,506.23 0.05 1.69 NSG-CT_WL(1) 404.70 0.53 317.28 404.69 212.99 2.41 -0.41 2,460,226.23 346,505.89 0.32 2.32 NSG-CT_WL(1) 504.70 0.68 319.51 504.69 312.99 3.20 -1.11 2,460,227.03 346,505.20 0.15 2.99 NSG-CT_WL(1) 604.70 0.83 321.30 604.68 412.98 4.22 -1.95 2,460,228.06 346,504.38 0.15 3.87 NSG-CT_WL(1) 704.70 0.83 322.25 704.67 512.97 5.36 -2.85 2,460,229.21 346,503.49 0.01 4.85 NSG-CT_WL(1) 804.70 0.74 322.63 804.66 612.96 6.45 -3.68 2,460,230.31 346,502.67 0.09 5.80 NSG-CT_WL(1) 904.70 0.58 329.07 904.65 712.95 7.39 -4.33 2,460,231.26 346,502.03 0.18 6.63 NSG-CT_WL(1) 1,004.70 0.50 334.88 1,004.65 812.95 8.22 -4.78 2,460,232.10 346,501.60 0.10 7.38 NSG-CT_WL(1) 1,104.70 0.39 331.59 1,104.64 912.94 8.92 -5.13 2,460,232.80 346,501.26 0.11 8.01 NSG-CT_WL(1) 2/9/2015 1:31:34PM Page 2 COMPASS 5000.1 Build 73 Halliburton • Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Soldotna CK Unit 341-04 Project: Soldotna CK Unit TVD Reference: SCU 416-04©191.70usft(Saxon 169(173.7'GL+18'I Site: Soldotna CK Unit MD Reference: SCU 416-04 @ 191.70usft(Saxon 169(173.7'GL+18'I Well: Soldotna CK Unit 341-04 North Reference: True Wellbore: SCU 41 B-04PB1 Survey Calculation Method: Minimum Curvature Design: SCU 41 B-04PB1 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Fasting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 1,204.70 0.28 342.23 1,204.64 1,012.94 9.45 -5.36 2,460,233.33 346,501.03 0.13 8.50 NSG-CT_WL(1) 1,304.70 0.04 127.28 1,304.64 1,112.94 9.66 -5.41 2,460,233.54 346,500.99 0.31 8.70 NSG-CT_WL(1) 1,404.70 0.16 128.63 1,404.64 1,212.94 9.55 -5.27 2,460,233.43 346,501.12 0.12 8.62 NSG-CT_WL(1) 1,504.70 0.50 99.75 1,504.64 1,312.94 9.39 -4.73 2,460,233.27 346,501.66 0.37 8.54 NSG-CT_WL(1) 1,604.70 0.41 97.05 1,604.64 1,412.94 9.27 -3.95 2,460,233.14 346,502.44 0.09 8.55 NSG-CT_WL(1) 1,704.70 0.39 98.05 1,704.63 1,512.93 9.18 -3.26 2,460,233.04 346,503.13 0.02 8.56 NSG-CT_WL(1) 1,804.70 0.23 126.82 1,804.63 1,612.93 9.01 -2.76 2,460,232.86 346,503.63 0.22 8.48 NSG-CT_WL(1) 1,904.70 0.23 144.75 1,904.63 1,712.93 8.73 -2.48 2,460,232.57 346,503.90 0.07 8.24 NSG-CT_WL(1) 2,004.70 0.21 137.87 2,004.63 1,812.93 8.43 -2.24 2,460,232.27 346,504.14 0.03 7.98 NSG-CT_WL(1) 2,104.70 0.24 142.59 2,104.63 1,912.93 8.13 -1.99 2,460,231.97 346,504.38 0.04 7.72 NSG-CT_WL(1) 2,204.70 0.51 138.97 2,204.63 2,012.93 7.62 -1.57 2,460,231.46 346,504.80 0.27 7.29 NSG-CT WL(1) 2,304.70 0.57 138.26 2,304.62 2,112.92 6.92 -0.95 2,460,230.74 346,505.41 0.06 6.69 NSG-CT_WL(1) 2,404.70 0.57 134.87 2,404.62 2,212.92 6.20 -0.27 2,460,230.01 346,506.08 0.03 6.08 NSG-CT_WL(1) 2,504.70 0.49 137.70 2,504.61 2,312.91 5.53 0.37 2,460,229.34 346,506.72 0.08 5.52 NSG-CT_WL(1) 2,604.70 0.60 137.21 2,604.61 2,412.91 4.83 1.02 2,460,228.63 346,507.35 0.11 4.93 NSG-CT WL(1) 2,704.70 0.62 133.61 2,704.60 2,512.90 4.07 1.76 2,460,227.86 346,508.09 0.04 4.29 NSG-CT WL(1) 2,804.70 0.54 140.03 2,804.60 2,612.90 3.34 2.46 2,460,227.12 346,508.77 0.10 3.68 NSG-CT WL(1) 2,904.70 0.53 141.33 2,904.59 2,712.89 2.61 3.05 2,460,226.39 346,509.36 0.02 3.06 NSG-CT_WL(1) 3,004.70 0.29 148.80 3,004.59 2,812.89 2.04 3.47 2,460,225.80 346,509.77 0.25 2.55 NSG-CT_WL(1) 3,104.70 0.19 158.65 3,104.59 2,912.89 1.67 3.66 2,460,225.43 346,509.95 0.11 2.21 NSG-CT_WL(1) 3,204.70 0.20 176.18 3,204.59 3,012.89 1.34 3.73 2,460,225.10 346,510.02 0.06 1.90 NSG-CT WL(1) 3,304.70 0.17 137.06 3,304.59 3,112.89 1.05 3.85 2,460,224.82 346,510.13 0.13 1.64 NSG-CT WL(1) 3,404.70 0.10 131.80 3,404.59 3,212.89 0.89 4.01 2,460,224.65 346,510.29 0.07 1.50 NSG-CT_WL(1) 3,504.70 0.03 134.10 3,504.59 3,312.89 0.81 4.10 2,460,224.57 346,510.38 0.07 1.44 NSG-CT_WL(1) 3,604.70 0.21 140.51 3,604.59 3,412.89 0.65 4.23 2,460,224.41 346,510.51 0.18 1.30 NSG-CT WL(1) 3,704.70 0.05 122.07 3,704.59 3,512.89 0.49 4.39 2,460,224.24 346,510.66 0.16 1.16 NSG-CT WL(1) 3,804.70 0.56 193.26 3,804.59 3,612.89 -0.01 4.31 2,460,223.75 346,510.58 0.55 0.66 NSG-CT_WL(1) I 3,904.70 0.58 195.47 3,904.58 3,712.88 -0.98 4.06 2,460,222.79 346,510.32 0.03 -0.33 NSG-CT_WL(1) 4,004.70 0.64 180.30 4,004.58 3,812.88 -2.02 3.93 2,460,221.74 346,510.17 0.17 -1.39 NSG-CT_WL(1) 4,104.70 1.01 165.28 4,104.57 3,912.87 -3.43 4.15 2,460,220.33 346,510.37 0.43 -2.75 NSG-CT_WL(1) 4,204.70 1.17 166.24 4,204.55 4,012.85 -5.28 4.61 2,460,218.48 346,510.81 0.16 -4.50 NSG-CT WL(1) 4,304.70 0.84 177.49 4,304.53 4,112.83 -7.00 4.89 2,460,216.75 346,511.07 0.38 -6.16 NSG-CT WL(1) 4,404.70 0.68 195.40 4,404.52 4,212.82 -8.31 4.76 2,460,215.45 346,510.92 0.28 -7.47 NSG-CT_WL(1) 4,504.70 0.52 184.54 4,504.52 4,312.82 -9.33 4.57 2,460,214.43 346,510.72 0.20 -8.51 NSG-CT_WL(1) 4,604.70 0.40 188.10 4,604.51 4,412.81 -10.13 4.48 2,460,213.63 346,510.62 0.12 -9.31 NSG-CT_WL(1) 4,704.70 0.19 190.02 4,704.51 4,512.81 -10.64 4.41 2,460,213.12 346,510.54 0.21 -9.82 NSG-CT_WL(1) 4,804.70 0.11 151.84 4,804.51 4,612.81 -10.88 4.42 2,460,212.87 346,510.55 0.12 -10.07 NSG-CT_WL(1) 4,904.70 0.23 205.00 4,904.51 4,712.81 -11.15 4.38 2,460,212.61 346,510.51 0.19 -10.34 NSG-CT WL(1) 5,004.70 0.60 245.96 5,004.51 4,812.81 -11.55 3.82 2,460,212.22 346,509.94 0.45 -10.81 NSG-CT_WL(1) 5,104.70 1.04 278.53 5,104.50 4,912.80 -11.62 2.44 2,460,212.16 346,508.56 0.62 -11.10 NSG-CT_WL(1) 2/9/2015 1:31:34PM Page 3 COMPASS 5000.1 Build 73 Halliburton • Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Soldotna CK Unit 341-04 Project: Soldotna CK Unit TVD Reference: SCU 41B-04 @ 191.70usft(Saxon 169(173.7'GL+18'F Site: Soldotna CK Unit MD Reference: SCU 41B-04 @ 191.70usft(Saxon 169(173.7'GL+18'I Well: Soldotna CK Unit 341-04 North Reference: True Wellbore: SCU 41 B-04PB1 Survey Calculation Method: Minimum Curvature Design: SCU 41 B-04PB1 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') I (ft) Survey Tool Name 5,204.70 1.21 291.14 5,204.48 5,012.78 -11.11 0.56 2,460,212.70 346,506.69 0.30 -10.89 NSG-CT_WL(1) 5,304.70 1.16 305.96 5,304.46 5,112.76 -10.13 -1.24 2,460,213.70 346,504.90 0.31 -10.20 NSG-CT_WL(1) 5,404.70 0.95 318.90 5,404.44 5,212.74 -8.92 -2.61 2,460,214.93 346,503.55 0.32 -9.21 NSG-CT_W1 (1) 5,504.70 0.96 314.00 5,504.43 5,312.73 -7.71 -3.75 2,460,216.16 346,502.42 0.08 -8.20 NSG-CT_WL(1) 5,604.70 0.91 310.95 5,604.42 5,412.72 -6.61 -4.96 2,460,217.27 346,501.23 0.07 -7.30 NSG-CT_WL(1) 5,704.70 0.32 299.34 5,704.41 5,512.71 -5 95 -5.80 2,460,217.94 346,500.39 0.60 -6.78 NSG-CT_WL(1) 5,804.70 0.61 309.69 5,804.41 5,612.71 -5.47 -6.45 2,460,218.43 346,499.75 0.30 -6.41 NSG-CT_WL(1) 5,904.70 0.60 301.39 5,904.40 5,712.70 -4.86 -7.31 2,460,219.05 346,498.90 0.09 -5.94 NSG-CT_WL(1) 6,004.70 0.26 305.74 6,004.40 5,812.70 -4.45 -7.94 2,460,219.46 346,498.27 0.34 -5.63 NSG-CT_WL(1) 6,104.70 0.11 291.88 6,104.40 5,912.70 -4.29 -8.21 2,460,219.64 346,498.00 0.16 -5.51 NSG-CT_WL(1) 6,204.70 0.34 310.18 6,204.40 6,012.70 -4.06 -8.53 2,460,219.87 346,497.69 0.24 -5.33 NSG-CT_WL(1) 6,304.70 0.16 184.10 6,304.40 6,112.70 -4.01 -8.77 2,460,219.92 346,497.45 0.45 -5.32 NSG-CT_WL(1) 6,404.70 0.26 248.99 6,404.40 6,212.70 -4.23 -8.99 2,460,219.70 346,497.23 0.24 -5.57 NSG-CT_WL(1) 6,504.70 0.18 270.69 6,504.39 6,312.69 -4.31 -9.36 2,460,219.63 346,496.86 0.11 -5.71 NSG-CT_WL(1) 6,604.70 0.15 279.65 6,604.39 6,412.69 -4.28 -9.64 2,460,219.66 346,496.57 0.04 -5.73 NSG-CT WL(1) 6,704.70 0.17 257.68 6,704.39 6,512.69 -4.29 -9.92 2,460,219.65 346,496.30 0.06 -5.78 NSG-CT WL(1) 6,804.70 0.19 250.91 6,804.39 6,612.69 -4.38 -10.22 2,460,219.57 346,496.00 0.03 -5.91 NSG-CT WL(1) 6,904.70 0.29 290.15 6,904.39 6,712.69 -4.35 -10.61 2,460,219.61 346,495.60 0.19 -5.94 NSG-CT_WL(1) 7,004.70 0.26 318.35 7,004.39 6,812.69 -4.09 -11.00 2,460,219.87 346,495.22 0.14 -5.75 NSG-CT_WL(1) 7,104.70 0.23 344.80 7,104.39 6,912.69 -3.73 -11.20 2,460,220.24 346,495.02 0.12 -5.42 NSG-CT_WL(1) 7,204.70 0.25 24.48 7,204.39 7,012.69 -3.33 -11.17 2,460,220.63 346,495.06 0.16 -5.03 NSG-CT_WL(1) 7,304.70 0.57 55.39 7,304.39 7,112.69 -2.85 -10.67 2,460,221.10 346,495.57 0.38 -4.47 NSG-CT_WL(1) 7,404.70 0.96 86.02 7,404.38 7,212.68 -2.51 -9.42 2,460,221.43 346,496.82 0.55 -3.94 NSG-CT_WL(1) 7,504.70 1.30 97.37 7,504.36 7,312.66 -2.60 -7.46 2,460,221.31 346,498.78 0.41 -3.73 NSG-CT_WL(1) 7,604.70 1.41 106.20 7,604.33 7,412.63 -3.09 -5.15 2,460,220.79 346,501.08 0.24 -3.85 NSG-CT_WL(1) 7,704.70 1.15 114.35 7,704.31 7,512.61 -3.84 -3.06 2,460,220.01 346,503.16 0.32 -4.27 NSG-CT_WL(1) 7,804.70 1.05 121.12 7,804.29 7,612.59 -4.73 -1.36 2,460,219.10 346,504.85 0.16 -4.89 NSG-CT_WL(1) 7,904.70 1.12 122.79 7,904.27 7,712.57 -5.73 0.25 2,460,218.08 346,506.44 0.08 -5.63 NSG-CT_WL(1) 8,004.70 1.11 121.32 8,004.25 7,812.55 -6.77 1.89 2,460,217.02 346,508.08 0.03 -6.39 NSG-CT_W1 (1) 8,104.70 0.89 128.03 8,104.24 7,912.54 -7.75 3.33 2,460,216.02 346,509.50 0.25 -7.14 NSG-CT_WL(1) 8,204.70 0.72 121.44 8,204.23 8,012.53 -8.56 4.48 2,460,215.20 346,510.64 0.19 -7.76 NSG-CT_WL(1) 8,304.70 0.70 125.15 8,304.22 8,112.52 -9.23 5.52 2,460,214.51 346,511.67 0.05 -8.27 NSG-CT WL(1) 8,404.70 0.37 133.94 8,404.21 8,212.51 -9.81 6.25 2,460,213.92 346,512.39 0.34 -8.72 NSG-CT_WL(1) 8,504.70 0.43 131.45 8,504.21 8,312.51 -10.28 6.76 2,460,213.44 346,512.90 0.06 -9.11 NSG-CT_WL(1) 8,604.70 0.45 128.90 8,604.21 8,412.51 -10.78 7.35 2,460,212.94 346,513.48 0.03 -9.51 NSG-CT_WL(1) 8,704.70 0.38 135.87 8,704.21 8,512.51 -11.26 7.89 2,460,212.45 346,514.01 0.09 -9.90 NSG-CT_WL(1) 8,804.70 0.21 112.29 8,804.20 8,612.50 -11.57 8.29 2,460,212.14 346,514.41 0.21 -10.14 NSG-CT_WL(1) 8,904.70 0.21 325.39 8,904.20 8,712.50 -11.49 8.35 2,460,212.22 346,514.47 0.40 -10.05 NSG-CT_WL(1) 9,004.70 0.32 354.87 9,004.20 8,812.50 -11.06 8.22 2,460,212.65 346,514.35 0.17 -9.65 NSG-CT_WL(1) 9,055.00 0.28 348.71 9,054.50 8,862.80 -10.80 8.19 2,460,212.91 346,514.32 0.10 -9.40 MWD_InterpAzi+gag(2) 2,9/2015 1:31:34PM Page 4 COMPASS 5000.1 Build 73 Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Soldotna CK Unit 341-04 Project: Soldotna CK Unit TVD Reference: SCU 41B-04 @ 191.70usft(Saxon 169(173.7'GL+18'F Site: Soldotna CK Unit MD Reference: SCU 41B-04 @ 191.70usft(Saxon 169(173.7'GL+18'F Well: Soldotna CK Unit 341-04 North Reference: True Wellbore: SCU 41B-04PB1 Survey Calculation Method: Minimum Curvature Design: SCU 41 B-04PB1 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 9,116.20 3.30 21.51 9,115.67 8,923.97 -9.01 8.80 2,460,214.69 346,514.96 5.01 -7.54 MWD_Interp Azi+sag(2) 9,208.48 7.38 23.74 9,207.53 9,015.83 -1.11 12.16 2,460,222.54 346,518.42 4.43 0.79 MWD_Interp Azi+sag(2) 9,272.80 9.04 24.50 9,271.18 9,079.48 7.27 15.92 2,460,230.87 346,522.29 2.59 9.65 MWD_InterpAzi+sag(2) 9,330.51 8.64 25.02 9,328.21 9,136.51 15.32 19.64 2,460,238.88 346,526.11 0.71 18.18 MWD_InterpAzi+sag(2) 9,392.50 9.86 25.54 9,389.39 9,197.69 24.33 23.89 2,460,247.83 346,530.48 1.97 27.74 MWD_InterpAzi+sag(2) 9,488.78 11.42 26.16 9,484.01 9,292.31 40.32 31.65 2,460,263.72 346,538.45 1.62 44.75 MWD+SC+sag(3) 9,550.22 13.39 27.94 9,544.02 9,352.32 52.07 37.67 2,460,275.39 346,544.61 3.27 57.28 MWD+SC+sag(3) 9,611.83 15.10 20.81 9,603.73 9,412.03 65.87 43.86 2,460,289.11 346,550.99 3.97 71.88 MWD+SC+sag(3) 9,672.30 15.29 11.07 9,662.10 9,470.40 81.06 48.19 2,460,304.24 346,555.52 4.23 87.56 MWD+SC+sag(3) 9,734.18 15.36 1.40 9,721.79 9,530.09 97.27 49.96 2,460,320.42 346,557.50 4.13 103.84 MWD+SC+sag(3) 9,796.37 15.10 0.60 9,781.80 9,590.10 113.60 50.24 2,460,336.75 346,557.99 0.54 120.02 MWD+SC+sag(3) 9,858.69 17.11 2.78 9,841.67 9,649.97 130.88 50.77 2,460,354.02 346,558.75 3.37 137.17 MWD+SC+sag(3) 9,908.00 17.11 2.78 9,888.79 9,697.09 145.37 51.48 2,460,368.50 346,559.64 0.00 151.60 PROJECTED to TD Checked By: Patrick Walker arbma,.,� � Approved By: Taylor ;,,,,"te Date: 2/9/2015 1:31:34PM Page 5 COMPASS 5000.1 Build 73 SCU 41B-04 Days Vs Depth 6500 —SCU 41B-04 Actual —SCU 41B-04 Plan 7000 1 -- 7500 —�_......._._ 8000 8500 --- 17, v a 9000 co m 9500 10000 10500 11000 �- 11500 0 5 10 15 20 25 30 35 40 Days SCU 41B-04 MW Vs Depth 8000 SCU 41B-04 Plan SCU 41B-04 Actual 8500 9000 1 9500 0 a v C) v a) 10000 10500 11000 11500 8.0 9.0 10.0 11.0 12.0 13.0 14.0 Mud Density(ppg) 214177 II Seth Nolan Hilcorp Alaska, LLC 0 GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 C 6 1 � � Tele: 907 777-8308 �J Hilrnrp.Mitokw.ILIA, Fax: 907 777-8510 2 5 4 6 2 E-mail: snolan@hilcorp.com MAR 0 2 2015 DATE 02/27/15 AOGCC D TA2GEED /2G M.K.BENDER To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL SCU 41B-04 and SCU 41B-04PB1 Elog, Mudlog,and Survey prints and digital data Prints: 2"/5" ROP-DGR-EWR MD 2"/5" DGR-EWR TVD 2" FORMATION EVALUATION MD 5" FORMATION EVALUATION MD 2" DRILLING ENGINEERING MD 2" GAS RATIO MD 2"/5" ROP-DGR-EWR MD PB1 2"/5" DGR-EWR TVD PB1 CD1: Elog digital data k CGM 2/11120153:52 PM File folder k DLL+LAS 2;1.1/20153:51 PM File fclder EMF 211/201.5 3:52 PM File folder .ii, PDF 2/11/2015 3:52 PM File folder ,i, Sal 41B-+0d-P61_Definiti.eSurrey 2,+1.1.,20153:52 PM File folder ', TIFF 2,11/2015 3:52 PM File folder CD2: Mudlog digital data 1, EMF Lcg Viewer 2/1612015 12:57 PM File folder 1, Halliburton Lcg Viewer 2/761201512:57 PM File folder j, SCU 41B-04 FINAL LOGS 2/'16/201512:57 PM File folder i, SCU 41B-04 LAS EXPORTS 216/2015 12:57 PM File folder f SCU 41B-04 FINAL END OF '!.ELL REPORT 21.6/201511:36 AM PDF Document 5,880 KB Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: / ,./.) 6,,,...„„4: 214177 II Seth Nolan Hilcorp Alaska, LLC 5 F n GeoTech 3800 Centerpoint Drive, Suite 100 "1 Anchorage, AK 99503 C Tele: 907 777-8308 2 5 4 6 1 Hihnrp,tusk.,.1.1 l RECEIVEL Fax: 907 777-8510 2 5 4 6 2 E-mail: snolan@hilcorp.com MAR 0 2 2015 AOGCC DATA DATE 02/27/15 3 LOGGED/21 M.K.BENDER To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL SCU 41B-04 and SCU 41B-04PB1 Elog, Mudlog, and Survey prints and digital data Prints: 2"/5" ROP-DGR-EWR MD 2"/5" DGR-EWR TVD 2" FORMATION EVALUATION MD 5" FORMATION EVALUATION MD 2" DRILLING ENGINEERING MD 2" GAS RATIO MD 2"/5" ROP-DGR-EWR MD PB1 2"/5" DGR-EWR TVD PB1 CD1: Elog digital data h, CGM 2,11/2015 3:52 PM File folder DLIS+LAS 2/11/20153:51 PM File folder c EMF 2111/2015 3:52 PM File folder 46 PDF 2/11/2015 3:52 PM File folder 416 SCU 41B-04+PB1_Definitive Survey 2111,/20153:52 PM File folder TIFF 2/11/2015 3:52 PM File folder CD2: Mud log digital data EMF Leg Viewer 2116/201512:57 PM File folder Halliburtcn Leghewer 2116/201512:57 PM File folder SCU41B-0i-1 FINAL LOGS 2116/20151257 PM File folder SCU 41B-04 LAS EXPORTS 2/16/201512:57 PM Filefolder la SCU 41B-+J$FINAL END OF WELL REPORT 2,/16/201511:36 AM PDF Document 5,880 KB Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: G /Jam J3e : Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Friday,January 30, 2015 11:04 AM To: 'Stan Porhola' Cc: Davies, Stephen F (DOA) Subject: RE:Verbal approval to change perf interval for SCU 41B-04 (PTD 214-177; Sundry 315-012) Stan, You have verbal approval to modify the perforation intervals as proposed below. The proposed new zones are within the approved range of depths (10396ft to 10802 ft). 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: Stan Porhola [mailto:sporhola(ahilcorp.com] Sent: Friday, January 30, 2015 8:47 AM To: Schwartz, Guy L(DOA) Cc: Davies, Stephen F(DOA) Subject: Verbal approval to change perf interval for SCU 41B-04 (PTD 214-177; Sundry 315-012) Guy, We are requesting verbal approval to add perf intervals in well SCU 41B-04(PTD 214-177; Sundry 315-012). Add the following: Hemlock H-4: 10,576'40,584' (8'), 6 spf Hemlock H-7: 10,723'-10,731' (8'), 6 spf Below are the currently approved intervals: Zone Sands Top (MD; Btm(MD) =T SPF -lerrlock H-1 10,396' 10,445' 49 6 Herrlock H-2 10,492' 10,552' Svc 6 iemlock H-3 10,552' 10,576' =4 6 -ierrlock H-5 10,600' 13,672' 6 -lemlock H-7 10,731' 10,802' -1 6 Regards, 1 Stan Porhola Operations Engineer Kenai Asset Team Hilcorp Alaska,LLC sporhola@hilcorp.com Office: (907) 777-8412 Mobile: (907) 331-8228 2 a) _ctin - _C O 4--+ C ^ a) 4_' 4-I -+-+ C •L _a C U - }, •- N CD E N o C 00 -0 U co -o a. - a) o C — •� _o • 0 0 rn o ago C -0 c0. E °� v a) ,' co D O O >% pp O O > +� of of c0 -Q o -0 a) ' _o a (4. p O N O o v O �.. co :Z O 0 -c O C O 4- 4p 01 C O Q cn f- O +-, r•I C 4-, cn O N •- Q1 C -C c6 r 1 cu U O Nco O C O CO _c O C E U LI) ..Q < F- D Ql 4.-1 LI_ D cm cn V) f �v\ I I -4414444, a) "V r O E I 0 0 O 00 C 60 00 m 0 O CU -0 D Q a °P N U o -C o m opNJ- o OF Th,1 evw I�j kV THE STATE Alaska Oil and Gas ,� ofALAS KA Conservation Commission 'Oh _ - 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS*1"- Fax' 907.276 7542 www aogcc.alaska.gov Stan Porhola Operations Manager Hilcorp Alaska, Inc. 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 41B-04 Sundry Number: 315-012 Dear Mr. Porhola: 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, /7)0t4Cte Cathy P. oerster Chair DATED this , day January,Janu , 2015 Encl. RECEIVED STATE OF ALASKA 01�`S ALASKA OIL AND GAS CONSERVATION COMMISSION /q.Ils JAN 0 5 ?015 0 3-11/4A APPLICATION FOR SUNDRY APPROVALS 0 75 C CC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod E Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate E • Pull Tubing❑ Time Extension❑ Operations Shutdowi❑ Re-enter Susp.Wel ❑ Stimulate❑ Alter Casing❑ Other. Initial Completion❑� 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number Exploratory ❑ Development 0 • 214-177 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service El 6.API Number: • Anchorage,Alaska 99503 50-133-10109-03 7.If perforating: '8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 1236 Soldotna Creek Unit(SCU)41 B-04 • Will planned perforations require a spacing exception? Yes ❑ No E 9.Property Designation(Lease Number). 10.Field/Pool(s): A028997 • Swanson River Field/Hemlock Oil . 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): 11,000' 10,828' 10,873' 10,720' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 22' 22" 22' 22 - Surface 3,000' 13-3/8" 3,000' 3,000' 2,730 psi 1,130 psi Intermediate Production 9,055' 7" 9,055' 9,055 6,340 psi 3,830 psi Liner 2,154' 4-1/2" 10,998' 10,826' 8,430 psi 7,500 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(It): N/A N/A N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(t)and TVD(ft): N/A;N/A WA/N/A;N/A/N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: • Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphies Development[� Service n 14.Estimated Date for 15.Well Status after prolosed work: Commencing Operations: 01/10/15 Oil Q . Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhda Email soorhola( hilcorD.corn Printed Name Stan Porhola Title Operations Engineer A--- Signature /9c*, Phone 907-777-8412 Date I/O S � � COMMISSION USE ONLY I Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 1 _ 01 L. n Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance LI Other: %, .3 5Cc So t 1_. } MiS I 1 '`) �r14:X L -I t! 1'u / 1-) Spacing Exception Required? Yes ❑ No [+� Subsequent Form Required: /C' " �' �1 ' APPROVED BY Approved by: / "7• P ?..0_,e_.„ 1,,,e„.___ COMMISSIONER THE COMMISSION Date: /— /3 -/Jr lh _I-7-0 Forth 10-403(Revised 10/20W2)'-- ORdiefiNSA*14111. t781 Ot ap��Qval. achmSenmind FDounnpicaantde / tt - Well Prognosis Well: SCU 41B-04 Hilcorp Alaska,LL Date: 1/05/2015 Well Name: SCU 41B-04 API Number: 50-133-101.0.9-03 Current Status: New Sidetrack Leg: N/A Estimated Start Date: January 10th, 2015 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-177 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Monty Myers (907) 777-8431 (0) (907) 538-1168 (M) AFE Number: 1413459C Current Bottom Hole Pressure: —2,815 psi @ 10,828' TVD (Based on offset wells, 0.26 psi/ft grad) Maximum Expected BHP: —2,815 psi @ 10,828' TVD (Based on offset wells, 0.26 psi/ft grad) Max. Allowable Surface Pressure: — 1,732 psi (Based on gas gradient of 0.10 psi/ft.) Brief Well Summary This well was drilled and completed with the Doyon Arctic Fox in May 2013. The well initial production was approximately 55 bbls of oil and 200 bbls of water per day on gas lift completion. A capillary string was run in July 2013 to aid dealing with downhole emulsions. Perforations were added to the Hemlock H-9 and the 3/8" capillary string re-ran to a deeper depth in September/October 2013.The capillary string was pulled in March 2014 and additional perfs were added in the Hemlock H-10 in April 2014. The well was plugged back in December 2014 with the Saxon#169 rig and sidetracked as SCU 41B-04. The purpose of this work/sundry is to run the completion with the drilling rig as a continuation of the drilling permit application. Notes Regarding Wellbore Condition • Well TD'd at 11,000' MD(10,828'TVD). Preparing to run 4-1/2" liner.- WO Rig Procedure: 1. ***Continue from Step 16.22 in PTD 214-177/APD*** 2. Change out rams to 2-3/8" pipe rams. RU 2-3/8"test joint. 3. Perform BOPE test of 2-3/8" rams.Test to 250 psi Low/3,500 psi High, annular to 250 psi Low/ 1,500 psi High (test for 10-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hrs in advance to witness. b. Notify BLM 48 hrs in advance of BOP test. 4. PU 3-1/4" mill and 4-1/2" casing scraper on 2-3/8"Tbg and XO to 4-1/2" DP and 7" Casing Scraper. 5. RIH w/3-1/4" mill to+/-30' above landing collar. 6. RU and pressure test liner lap to 3,000 psi for 30 min and chart. 7. RIH to tag liner top at+/-8,844' with 7" casing scraper. a. Setup BHA to have 3-1/4" mill to +/-30' above landing collar. 8. Circ 75 bbl chem wash (25 bbl caustic, 25 bbl surfactant, 25 bbl hi-vis pill). 9. Circulate well clean w/3% KCI fluid (filter fluid going downhole). 10. POOH. LD 3-1/4" mill,4-1/2" Casing Scraper, 7" Casing Scraper. a. Lay down the 2-3/8"tubing. 11. MIRU E-line. 12. RIH and run cement bond log from PBTD to 8,800' MD. 13. RIH and run PNL log from PBTD to 10,000' MD. Well Prognosis Well: SCU 41B-04 Hileorp Alaska,LL Date: 1/05/2015 14. RD E-line. 15. RU 3-1/2"test joint. 16. Perform BOPE test of 2-7/8" x 5"VBR on 3-1/2".Test to 250 psi Low/3,500 psi High, annular to 250 psi Low/1,500 psi High (test for 10-min). Record accumulator pre-charge pressures and chart tests. c. Notify AOGCC 24 hrs in advance to witness. d. Notify BLM 48 hrs in advance of BOP test. 17. PU 3-1/2" packer and completion jewelry and 3-1/2"tubing and RIH and set packer at+/-8,810' MD. a. Leave tubing tail to land +/- 5' above liner top at+/-8,844' MD. b. Use conventional bands to secure chemical injection line to tubing. c. Space out Gaslift Mandrels per proposed schematic. d. Run dummy valves in all Gaslift Mandrels. e. Run dummy valve in Chemical Injection Mandrel. 18. MIRU Slickline. 19. RIH w/2.50"x20' dummy gun to PBTD. a. Maximum deviation is 34°. 20. RIH and set RHCP plug body in X-profile. 21. RIH and set RHCP ball and rod. Keep setting tools latched. 22. Pressure up to 3,500 psi and set hydraulic packer. 23. Test tubing to 3,500 psi for 30 min and chart. 24. Pull RHCP ball and rod. RD Slickline. \3` 25. Test casing to 3,000 psi for 30 min and chart!._ N \{ 26. Lay down landing joint.Set BPV. ND BOPE. NU tree. Pull BPV. 27. Set TWC.Test hanger to 250/3,500 psi.Test tree to 250/5,000 psi. Pull TWC. 28. RD Saxon#169 Drlg Rig. 29. Turn well over to production in preparation of moving off the Saxon#169 Drlg Rig. 30. Replace IA x OA pressure gauge if removed (7" x 11-3/4"). Slickline Procedure: 31. MIRU Slickline, PT Lubricator to 3,000 psi Hi 250 Low. a. Tree connection is 3.5" Bowen. 32. RIH and pull dummy valves from each gaslift mandrel (5 mandrels). POOH. 33. RIH and pull dummy valve from the chemical injection mandrel. POOH. 34. RIH and set live valve in chemical injection mandrel. POOH. a. Set spring pressure to 3,000 psi. 35. RIH and set live valves in each gaslift mandrel (5 mandrels). POOH. 36. RIH and pull RHBC plug body from X-profile. POOH. 37. RIH w/2.50"x20' dummy gun to PBTD. E-line Procedure: 38. Rig up gas lift lines to tree. Production to gaslift off top of well to achieve desired underbalance. a. Est BHP= 2,750 psi. Est hydrostatic= 2,000 psi. (Fluid level at GLM #1 at 8,744' MD and SITP of 800 psi) 39. MIRU E-line, PT Lubricator to 3,000 psi Hi 250 Low. a. Tree connection is 3.5" Bowen. 40. RU 2.5"" 6 spf HC wireline guns (6 spf shot density). 41. Bleed tubing pressure down to below 800 psi, as directed by Reservoir Engineer. 42. RIH and perforate the following intervals: Well Prognosis Well: SCU 41B-04 Ililcora Alaska,LL' Date: 1/05/2015 Zone Sands Top (MD) Btm (MD) FT SPF Hemlock H-1 10,396' 10,445' 49 6 Hemlock H-2 10,492' 10,552' 60 6 Hemlock H-3 10,552' 10,576' 24 6 Hemlock H-5 10,600' 10,672' 72 6 Hemlock H-7 10,731' 10,802' 71 6 a. Proposed perfs shown on the proposed schematic in red font. b. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. c. Correlate using proposed Cement Bond log. (Tie-in log depth is pending). d. Record tubing pressures before and after each perforating run. 43. RD E-line. 44. Turn well over to production. E-line Procedure (Contingency): 1. If any zone produces sand and/or water. 2. MIRU E-line, PT lubricator to 3,000 psi Hi 250 Low. a. Tree connection is 3.5" Bowen. b. SITP will be+/-800 psi (remaining gas lift). 3. RIH and set 4-1/2"thru tubing plug at depth above zone. Attachments: 1. Proposed Schematic 2. BOPE Schematic 3. Choke Manifold Schematic ► Swanson River Unit Well: SCU 4113-04 PROPOSED SCHEMATIC Ctoposed PTD: 2omple14on-177P Hilcorp Alaska,LLC API: 50-133-10109-03 KB-THF: 17.83' CASING DETAIL J 1 _ Size Type Wt Grade Conn. ID Top Btm 22'Q 2 , 22" Conductor Surf 22' 13-3/8" Surf.Csg 54.5 J-55 STC 12.615" Surf 3,000' DV Collar 29 N-80 BTC 6.184" Surf 304' 2,002' 26 N-80 BTC 6.276" 304' 1,235' 7" Production Casing 23 N-80 BTC 6.366" 1,235' 4,229' 3 26 N-80 BTC 6.276"" 4,229' 4,527' 13-3/8" 29 N-80 LTC 6.184" 4,527' 6,489' 26 N-80 LTC 6.276" 6,489' 9,055' 4-1/2" Production Liner 12.6 L-80 DWC/C-HT 3.958" 8,844' 10,998' 4E TUBING 4 3-1/2" Production Tubing 9.3 L-80 8RD 2.992 0' 8,842' i'' , S' JEWELRY DETAIL iu 5 No. Depth ID OD Item 1 18' 2.992" - Tubing Hanger,3-1/2"8RD Box x 3-1/2"8RD Box Ili „ DV Collar 2 19' 2.992" 3.500" Pups,3-1/2"8RD oo 6,944' 3 2,634' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#5 6 i r* 4 4,705' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#4 5 6,493' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#3 10 ,�����,����f',,'''' 6 7,803' 2.992" 5.250" 3-1/2"SF0-1 Mandrel 8RD GLV#2 ;1 7 8,744' 2.992" 5.250" 3-1/2"SFO-1 Mandrel 8RD GLV#1 Orifice �i r 8 8,792' 2.992" 5.250" Chemical Injection Mandrel 0 7 IIIIS 1 k 9 8,810' 3.000" 5.875" Hydraulic Packer ii,1 9 10 8,831' 2.813" 4.500" X-Nipple 8 11 8,842' 2.992" 4.500" WL Entry Guide I t I 1 I °+1 Short RA Marker Joints 944. @ 10,342'-10,356'MD 4 - ,,' @ 10,557-10,565'MD 74i' 10 X r' @ 10,685'-10,699'MD 0@ 10,77W-10,792'MD '4 11 = "r IP ' PERFORATIONS 7" "',r 1 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date CBL(EST) H1 10,396' 10,445' 10,320' 10,361' 49' 6 2-1/2"HC Proposed 8,844' le j H2 10,492' 10,552' 10,400' 10,450' 60' 6 2-1/2"HC Proposed H3 10,552' 10,576' 10,450' 10,470' 24' 6 2-1/2"HC Proposed 4 Ail H5 10,600' 10,672' 10,490' 10,550' _ 72' 6 2-1/2"HC Proposed RA Mrk Jt H7 10,731' 10,802' 10,600' 10,660' 71' 6 2-1/2"HC Proposed H-1 a H-2 RA Mrk Jt ;. H- ;-if - Iv._jr Contingency H-5 Thru-Tubing Plugs RA Mrk Jt ' ;; RA Mrk Jt I ll-7 WELL DATA >' _ PTD:214-177 .i +)R API: 50-133-10109-03 *mac, Lease: FEDA-028997 4-1/2"�w3" il 6"Hole Spud Date:12/24/2014 TD=11,000'MD-10,828'ND Max Deviation 34"@ 10,414' Tree cxn: 3.5"Bowen PBTD=10,873'MD—10,720'ND Max Dogleg 6.6°/100'@ 9,147' Lift Threads: 3-1/2"8RD Downhole Proposed Updated by STP 1/05/15 SCU 41 B-04 HCompletion Procedure Rev 0 118rorp Ua.l.a.111 BOPE Schematic • r-. 1 III lel iii iii iii ii iiia rel 3.;.. [ j OLdr'.u11 iii iii Ill III III — 'il � 2-7/8"x 5"VBR i. r .ii X11 T3 3snclgy-Pal-. ()sit ode l'OR 2 ''''11110111111 _.. • I1" 'OUC - III'_ 11"Blind III 181181 lei iii .. iftra "f z.00' IOIIfe..a:]IIr:4, 1e111I:• u r 2 1/16 SM Kill Side 1/8 5M Choke Side s i 1 3 Eno 1.41 ..... mi cMc4 . _. 2-3/8"Pipe Ram w: i t"Soca , _ 1!' 111181 1e1 III Grade I. lei lei lei fill les 11111 lip—'1,4141-. _ IT gPs 4' I: ' .... ,ice I. ' i 111 {9 Y lit I irl -m mg ilk I in 1; iL 5/8" Revision 0 January, 2015 • SCU 41B-04 HCompletion Procedure Rev 0 Ililrorp.tla,ka,1.1.1 Choke Manifold Schematic f/ /e? n kir, /47 ; f,. C,.,- z,,: _ 67 24 413.62 43 62 I.,1.1';81 O o '• 0 r � —1043 —14.62 1467 1.43— • � /iir-0.19 -019 AlkIlion a" — 'AAj ` r0.19__ 019 r-4' r j0 �,, ii f Q1: , 1 9IX ,•�:1:\f?PO` 11,70 ■ `:'.'I'• 91°° C . Gi 4s .."..1:N...!\ 9.00 .r. ._1-9.. t i. 1I (tom 111.1•Z i•� i ►r1►{ ,,: I, - J 7I aI9J 30 t7 NIN11N1N1 0.19J I --0 C' •G19 lio 0 Nil I x0.19 �w (. 0 © lia 1n 9.84 u= I 64 .. .o I mum aI9J ;air ==, J lir 38 03 ^L N1 uP 1a1 U. a19 10 .54 ,46a !1 11 7 4140.1 1 �' 14623603 J•..V- y', 1� �, 'p� 18.67 R .... I II 1 01111111...11;2101..... a19 . /,.. o.19J io 50 z.••• Illi i r.1,-‘,... :Irril :. lwir,s .., • P. •:..54. 111' il C J.,..LI—an ® �� ;yy�( 112 1:51048IO<E ,� / y:� -019 -0.'9 0.19 - ,_ .AtlUAI ` 1 0.19-- -019 057.11411011 —631 —1462 —14.62 14.62— 14.62---6.31 P141+~ 4162 43.62 Poi Wet 87.24 1 M, r K.Ke } ...,.. CAO ..ter._ fir 510M, 1.LAYOUT 971M R GAMIN . _ . . b 1197 arc w ..,'- e4.. 1 r��;_ SAX.POKY.F�9� Y'.i Sf � .n'4.......,.:;?:,;.,- -' Area 0T..111111 Pe 6802 0 ...... r'''•1 ".� .•aR.1hl]{6..111M Revision 0 January, 2015 g.,,,, -v1, ojALAsKA rIv or T",�' • „ , STATE Alaska Oil and Gas ������rjy_ Conservation Commission i -�•iti h_ __ _ _ _ 333 West Seventh Avenue � Anchorage,Alaska 99501-3572 C I i()\ EPN(1P B1I 1 `��7ALIk I-R Main:907.279.1433 0 Fax:907.276.7542 4LA6 www.aogcc.alaska.gov Monty M. Myers Drilling Engineer Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 41B-04 Hilcorp Alaska, LLC Permit No: 214-177 Surface Location: 961' FNL, 1127' FEL, Sec. 4, T7N, R9W, SM, AK Bottomhole Location: 371' FNL, 1017' FEL, Sec. 4, T7N, R9W, SM, AK Dear Mr. Myers: Enclosed is the approved application for permit to re-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: The minimum acceptable logging suite is gamma ray/resistivity from kick off point to total depth. 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, e,j6,7 i.' „.,,,,i,/„ Cathy P. Foerster Chair DATED this ety of December, 2014. t.Ur.! V MU, STATE OF ALASKA i C T 9 9 2014 ! A OIL AND GAS CONSERVATION COMP )N PERMIT TO DRILL AOGCC 20 AAC 25.005 la.Type of Work: lb.Proposed Well Class: Development-Oil Q • Service- Winj ❑ Single Zone ❑ 1 c.Specify if well is proposed for: Drill ❑ Lateral ❑ Stratigraphic Test 0 Development-Gas 0 Service-Supply ❑ Multiple Zone ❑ Coalbed Gas 0 Gas Hydrates 0 • Redril❑✓ Reentry 0 Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas 0 2.Operator Name: 5. Bond: Blanket 0 Single Well 0 11.Well Name and Number: Hilcorp Alaska,LLC Bond No. 042C 352 Z ti.. 4.•'41i SCU 41B-04 • 3.Address: 6.Proposed Depth. 12.Field/Pool(s): 3800 Centerpoint Drive,Suite 1400,Anchorage,AK,99503 MD. 11,000' • TVD: 10,875'. Swanson River Field/ 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Hemlock Oil Pool • Surface: • 961'FNL,1127'FEL,Sec 4,T7N,R9W,SM,AK • A028997 Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 394'FNL, 1020'FEL,Sec 4,T7N,R9W,SM,AK N/A December 12th,2014 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 371'FNL, 1017'FEL,Sec 4,T7N,R9W,SM,AK 2560 acres 6,287' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: . 192.3 feet 15.Distance to Nearest Well Open Surface: x-346506.3 • y-2460223.8 . Zone-4 GL Elevation above MSL: .173.7 feet to Same Pool: 1370'(SCU 332-04) 16.Deviated wells: Kickoff depth: 8600 feet . 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 29 degrees Downhole:;.;,ri 4900 psig - , (Surface: 1739 psig 18.Casing Program: Specifications Tol3"tetting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 6" 4-1/2" 12.6# L-80 DWC/C HT 2600 8400 8400 11000 10875 65 bbls 15.3 ppg 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): 10,807' 10,758' 10,777' 10,777' 10,730' None Casing Length Size Cement Volume MD TVD Conductor/Structural 22 22 - 22 22 Surface 3000 13-3/8 - 3000 3000 Intermediate 9520 7" - 9520 9520 Production Liner 10758' 4-1/2" - 10758' 10730' Perforation Depth MD(ft): 10,417'to 10,598'MD. Perforation Depth TVD(ft): 10,389'to 10,560'TVD 20. Attachments: Property Plat ❑✓ BOP Sketch Q Drilling Program ❑� Time v.Depth Plot Q Shallow Hazard Analysis❑ Diverter Sketch p Seabed Report 0 Drilling Fluid Program Q 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Email Printed Name Monty M Myers Title Drilling Engineer Signatur �� Phone 907-777-8431 Date 10/28/2014 Commission Use Only Permit to Drill �7 API Number: / ��•,Permit Approval l I q See cover letter for other Number: �� / 50 j 3 ��U(v��� L�tJ Date: 1 a y 1 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. Er .-14- '3 s 0Other: .,� 1 n S L / c� -,f- Samples req'd: Yes 0 No[ Mud log req'd:Yes No[( 1 H2S measures: Yes❑ No[�/ Directional svy req'd:Yes No❑ a 4-. C ✓� L Spacing exception req'd: Yes❑ No[ Inclination-only svy req'd:Yes No[v] �Lie.,:-L C 'T APPROVED BY 1 / Approved by. COMMISSIONER THE COMMISSION Date:/Z -gJ -/ 7 Z 3. 11 /1 A 'A Submit Form and Form 10-4 (Revised 10/2012) T r i i li r nths from the date of approval(20 AAC 25.405 ) Attachment n Duphcate30 Monty Myers Hilcorp Alaska, LLC Drilling Engineer P.O. Box 244027 Hilcorp Anchorage,AK 99524-4027 Snow, Tel 907 777 8431 Company Email mmyers@hilcorp.com 10/20/14 RECEIVED Commissioner Alaska Oil&Gas Conservation Commission OCT h 9 2014 333 W. 7th Avenue AOGCC Anchorage,Alaska 99501 Re: SCU 41B-04(SCU 41A-04 ST) Dear Commissioner, Please find enclosed the 10-401 Application for Permit to Drill for the SCU 41B-04. SCU 41B-04 is a development oil well planned to be re-drilled in a Northerly direction from SCU 41A- 04 utilizing the existing casing program down to 8600' MD / 8600' TVD. At 8600' MD te�parent 'aveilbore will be sidetracked and new wellbore drilled penetrating several Hemlock targets. A 2400' x 6" open hole section is planned. A 4-1/2" 12.6# L-80 DWC/C prod liner will be run, cemented, and perforated based on LWD data obtained while drilling the interval. The well will be completed with a gas lift assembly on 3-1/2" production tubing. Drilling operations are expected to commence approximately December 12th, 2014. 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. A separate sundry notice will be submitted to cover P&A and wellbore preparation for the sidetrack. General sequence of operations pertaining to this approved drilling procedure: • MOB Saxon Rig#169 to SCU 41B-04, NU and test BOPE(5 days) • Perform clean out run to plug (-8650')and test casing. Displace to mud. (1 day) • Set Whipstock, mill 6"window at 8600'. Perform FIT to 12.5 ppg (2 Days) • Drill 6" production hole from 8600'to 11000' MD. (6 Days) • Perform short trip and condition mud. POOH (1 day) • LD Directional Tools. RIH w 4-1/2" liner. Set liner and cement. Circ wellbore clean. (1 Days) • POOH, laying down DP and liner running tools, ND BOPE (1 day) • RDMO(1 Day) If you have any questions,please don't hesitate to contact myself at 777-8431 or Paul Mazzolini at 777-8369. Sincerely, Monty Myers Drilling Engineer Hilcorp Alaska, LLC Page 1 of 1 Hilcorp Alaska, LLC SCU 41B-04 (SCU 41A-04 ST) Drilling Program Soldotna Creek ' '-- , ro d by: Mt My Revision 0 October 20, 2014 SCU 41 B-04 Drilling Procedure Rev 0 IliIcorp Ala+ka.1.1.1 --- 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 Summary 7 8.0 Mandatory Regulatory Compliance/Notifications 8 9.0 R/U and Preparatory Work 11 10.0 BOP N/U and Test 12 11.0 Mud Program and Density Selection Criteria 13 12.0 Whipstock Running Procedure 14 13.0 Whipstock Setting Procedure 17 14.0 Drill 6"Hole Section 19 15.0 Run 4.5"Production Casing 22 16.0 Cement 4.5" Production Casing 25 17.0 RDMO 28 18.0 BOP Schematic 29 19.0 Wellhead Schematic 30 20.0 Days vs Depth 31 21.0 Geo-Prog 32 22.0 Anticipated Drilling Hazards 33 23.0 Rig Layout 34 24.0 FIT Procedure 35 25.0 Choke Manifold Schematic 36 26.0 Casing Design Information 37 27.0 6"Hole Section MASP 38 28.0 Plot(NAD 27) (Governmental Sections) 39 29.0 Surface Plat(As Built) (NAD 27) 40 30.0 Surface Plat(As Built) (NAD 83) 41 31.0 Directional Program (P1) 42 SCU 41B-04 Drilling Procedure Rev 0 Meng;Ala.ka,LLf. 1.0 Well Summary Well SCU 41B-04 Pad&Old Well Designation Sidetrack of existing well SCU 41A-04 (PTD#213-028) Planned Completion Type 4-1/2" 12.6#L-80 Liner Target Reservoir(s) Hemlock Planned Well TD, MD/TVD 11000' MD/ 10875' TVD PBTD, MD/TVD 10880' MD/ 10755' TVD Surface Location(Governmental) 961' FNL, 1127' FEL, Sec 4, T7N,R9W, SM,AK Surface Location(NAD 27) X=346506.271,Y=2460223.814 Surface Location(NAD 83) X=1486529.131,Y=2459985.048 Top of Productive Horizon (Governmental) 394'FNL, 1020'FEL, Sec 4, T7N,R9W, SM,AK TPH Location(NAD 27) X=346604.91,Y=2460781.74 TPH Location(NAD 83) X=1486627.784,Y=2460542.979 BHL(Governmental) 371'FNL, 1017'FEL, Sec 4, T7N,R9W, SM,AK BHL(NAD 27) X=346608.56,Y=2460805.18 BHL(NAD 83) X=1486631.435,Y=2460566.419 AFE Number 1413459D AFE Drilling Days 19 AFE Drilling Amount $3.4 MM Work String 4-1/2" 16.6# S-135 CDS-40 RKB—AMSL 18.6' KB—192' AMSL Ground Elevation 173.7' AMSL BOP Equipment 11" 5M T3-Energy(Model 7082)Annular BOP 11" 5M T3-Energy(Model 6011i)Double Ram 11" 5M T3-Energy(Model 6011i) Single Ram Page 2 Revision 0 October, 2014 SCU 41B-04 Drilling Procedure Rev 0 II lrnrlr Va.ka. 2.0 Management of Change Information Hilcorp Alaska, LLC Hilco Grp Eaeiy Changes to Approved Permit to Drill Date: October 20,2014 Subject: Changes to Approved Permit to Drill for SCU 41B-04(SCU 41A-04 ST) File#: SCU 41B-04(SCU 41A-04 ST)Drilling Program Any modifications to SCU 41 B!-04 Drilling Program will be documented and approved below. Changes to an approved APD will be,c9maitiniefrtet4erthe BLM and AOGCC_ �� P r v z.c �Zv ar=c 1✓cZ Ke.^ - ' ' ,` ,,>,i�C iiC Sec Page Date Procedure Change / ✓ Approved Approved By By Approval: Drilling Manager Date Prepared: Drilling Engineer Date Page 3 Revision 0 October, 2014 SCU 41B-04 Drilling Procedure Rev 0 IIikorp:%lacka,IAA: 3.0 Tubular Program Hole Section OD (in) Wt(#/ft) Coupl OD ID(in) Drift(in) Grade Conn Top Bottom 4-1/2" 12.6 5.0'" 3.918 3.833 L-80 DWC/C 8400 11000 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) 6" 4-1/2" 3.826 2-11/16- 5-1/4" 16.6 S-135 CDS-40 17693 16769 595k All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 4 Revision 0 October, 2014 SCU 41 B-04 Drilling Procedure Rev 0 Meng,ilrnrp I.I.I: 5.0 Internal Reporting Requirements 5.1 Fill out daily drilling report and cost report on Wellez. i. Report covers operations from 6am to 6am ii. 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. iii. Ensure time entry adds up to 24 hours total. iv. 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 i. Submit a short operations update each work day to pmazzolini@hilcorp.com, lkeller@hilcorp.com, nunyers@hilcorp.com and jbarrett@hilcorp.com 5.3 5am Weekend Update i. Submit a short operations update each weekend and holiday to whoever is assigned weekend or vacation duty. Details will be sent before each weekend or holiday. ii. Copy pmazzolini@hilcorp.com, lkellera,hilcorp.com and mm_yers@hilcorp.com 5.4 EHS Incident Reporting i. 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 ii. Notify Drlg Manager 1. Paul Mazzolini: 0: 907-777-8369 C: 907-317-1275 iii. Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally i. Send final"As-Run"Casing tally to mmyersca,hilcorp.com and jbarrett@hilcorp.com 5.6 Casing and Cmt report i. Send casing and cement report for each string of casing to mmyers@hilcorp.com and jbarrett@hilcorp.com Page 5 Revision 0 October, 2014 SCU 41 B-04 H Drilling Procedure Rev 0 Hilrorp Alaska,LLL 6.0 Planned Wellbore Schematic II Swanson River Unit Well: SCU 418-04 PROPOSED SCHEMATIC Pro: 213-028 API: 50-133-10109-02 Hiker,,Ala..ka.I.I.0 EXISTING CASING DETAIL r Size Type Wt Grade Conn ID Top Bu n zx-fJ ''2.,..,®. condnctar t„�.,.,.,,... surf 22' 13-3197 SWI.Ss9 + 54.3 1.53 STC 12.013' surf 3.000' I !! . DV Cellar 29 14-130BTC 0.144' Surf 304' 11 7COT 20 N-BD 1 BTC 5110” 304' 1133' .t.t 23 N-SD 1 STC 0.300 1,235' 4,229' w ' 1' Praductlon Cants ' 20 N-BO BTC 01704,527'4,229' /AZd"-2 f..71a•ia , 29 N-B_0 1 LTC 0 184 4,717' 0,409' - Sittz'- .� 20 N-BD LTC 0376' 0,499' 5,34-117— ----- ,340' t., 29 N-80 LTC 0.1.06 9,340' 9,391' `+ 4-1/2' Production Uner 12.0 LBO DWC/C-HT 3_936' 9,393' 10,790' 4 ?!s PROPOSED JEWELRY DETAIL t NO. Depth RS 00 Rem 1 5.400' r X 4-1/2-DSP liner hanger P MOW 00'-11,000' 4-1/2'12.04L-IOOWC/C OV Collar 5, 6,944• •i! t> INCUNATION DETAIL KOP: 0007'M11/8003'TVO Build: 7.02/100' Hold: 299 from 9221'-9791'MD it 4 Drop: 4.37/100'to 21,from 9791'-11000'MD . Inclination at TD: 2r �: ' Azimuth: 777 at8023"MD&Ile to TO A lo Ert r �) - 1 ` S-f r j Y IL 1 CEMENT DETA TOC 8400'MD/8400'TVD V".��qV.�0 VOL 03 hht3/303 ft3 DENS: 171 ppb 9 t' '4, 2 f. f 704 'vd'. a'Ma4Y .-to-TY° ' .. TD a 11,00'MD—10,875'ND Mee Drrlataon 29'81.9,231' P510 a 10,880'MD-10,731'TVO Mat Dogleg 9'/100'm 9.221' Page 6 Revision 0 October, 2014 SCU 41 B-04 HDrilling Procedure Rev 0 Ilileorp Alaska.I.1.0 7.0 Drilling Summary SCU 41B-04 is a development oil well planned to be re-drilled in a Northerly direction from the recently sidetracked SCU 41A-04 utilizing the existing casing program down to 8600' MD/8600' TVD. At 8600' MD the parent wellbore will be sidetracked and new wellbore drilled penetrating several Hemlock targets. A 2400' x 6"open hole section is planned. A 4-1/2" 12.6# L-80 DWC/C prod liner will be run, cemented, and perforated based on LWD data obtained while drilling the interval. The well will be completed with a gas lift assembly on 3-1/2"production tubing. Drilling operations are expected to commence approximately December 1st, 2014. 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. Jj A separate sundry notice will be submitted to cover P&A and wellbore preparation for the sidetrack 4l and for running the completion assembly (2) — General sequence of operations pertaining to this approved drilling procedure: e4 A 1. MOB Saxon Rig #169 to SCU 41B-04, NU and test BOPE (5 days) +3..... 2. Perform clean out run to plug (8650') an test casing. Displace to mud. (1 day) Set Whipstock, mill 6" window at 8600'. erform FIT to 12.5 ppg (2 Days) 4. Drill 6" production hole from 8600' to 11000' MD. (4 Days) 5. Perform short trip and condition mud. POOH (1 day) rD 6. LD Directional Tools. RIH w 4-1/2" liner. Set liner and cement. Circ wellbore clean. (1 Days) 7. POOH, laying down DP and liner running tools,ND BOPE (1 day) 8. RDMO (1 Day) Page 7 Revision 0 October, 2014 SCU 41 B-04 Drilling Procedure Rev 0 Ilikvirp Alur ku,LLC 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 of SCU 41B-04. 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 10/10 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 both AOGCC and BLM approved drilling permit is posted on the rig floor and in Co Man office. Variance Requests: t f` • Onshore Oil and Gas Order No. 1, Section III. D. 3. C. n,/t�. O re -J'' ' o Hilcorp requests approval to install a 2-1/16" 5M HCR valve on kill line in lieu of a check valve. Operator suspects a freeze plug risk associated with installation of a check valve in the kill line. Ad,C c— o Hilcorp requests approval to utilize flexible choke and kill lines in lieu of hard piping. Page 8 Revision 0 October, 2014 HSCLJ41B-04 Drilling Procedure Rev 0 flilrnrp Alaska,L1.1: Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure(psi) • 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 6" • 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. Required BLM Notifications: • 48 hours before spud. Follow up with actual spud date and time. • 48 hours before casing running and cmt operations • 48 hours before BOPE tests • 48 hours before logging, coring, &testing • Any other notifications required in APD. Additional requirements may be stipulated on APD. Page 9 Revision 0 October, 2014 SCU 41 B-04 HDrilling Procedure Rev 0 nitrorp Alaska,l.l.c 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@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) BLM Justin Miller/BLM Petroleum Engineer/ (0): 907-271-3406 (C): 907-717-4039 Use the below email address for BOP notifications to the BLM: BLM_AK_AKSO_EnergySection_Notifications@b1m.gov Page 10 Revision 0 October, 2014 I/ HSCU41B-04 Drilling Procedure Rev 0 Ililcorp Alaska,1.1,C 9.0 R/U and Preparatory Work 9.1 A separate sundry will be submitted that will include the following: • MIRU workover rig. • Set BPV, remove tree. 3/4( • N/U and test BOP. • Pull existing production tubing. Plug back well with cmt. • Tag & pressure test cmt plug. • Run and set a CIBP at 8650' MD. • RDMO workover rig. 9.2 Level pad and ensure enough room for layout of rig footprint and R/U. 9.3 Layout Herculite on pad to extend beyond footprint of rig. 9.4 R/U Saxon Rig #169, spot service company shacks, spot & R/U company man&toolpusher offices. 9.5 After rig equipment has been spotted, R/U handi-berm containment system around footprint of rig. 9.6 Mix mud for 6" hole section. 9.7 Set test Plug in wellhead prior to N/U BOP to ensure nothing can fall into the wellbore if it is accidentally dropped. 9.8 Verify 5" liners installed in mud pumps. • HHF-1000 Pumps are rated at 3457 psi(80%) with 5" liners and can deliver 306 gpm at 120 spm. This will allow us to drill the 6"hole section with (1) mud pump. Page 11 Revision 0 October, 2014 SCU 41B-04 Drilling Procedure Rev 0 Ilileorp Alaska,1.1.1: 10.0 BOP N/U and Test 10.1 N/U 11"x 5M BOP as follows: • BOP configuration from Top down: 11" x 5M annular BOP/11" x 5M double ram/11" x 5M mud cross/11"x 5M single ram. • Double ram should be dressed with 2-7/8" x 5" VBR in top cavity, blind ram in btm cavity. • Single ram should be dressed with 2-7/8" x 5" VBR. • N/U bell nipple, install flowline. 10.2 Run 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 "A" section side outlet valves open during BOP testing so pressure does not build up beneath the test plug. Confirm the correct valves are opened!!! • Test VBRs on 4-1/2"test joint. • Ensure gas monitors are calibrated and tested in conjunction w/BOPE. 10.3 R/D BOP test assy. 10.4 Continue mixing mud for 6" hole section. 10.5 Set wearbushing in wellhead. Ensure ID of wearbushing> 7". Page 12 Revision 0 October, 2014 SCU 41B-04 Drilling Procedure Rev 0 ltilrorp Alaska,1.1.1: 11.0 Mud Program and Density Selection Criteria 11.1 6" Production hole mud program summary: Primary weighting material to be used for the hole section will be Calcium Carbonate to minimize solids. We will have barite on location to weight up the active system 1ppg above highest anticipated MW in the event of a well control situation. 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 6%KCl/P1-1'A fresh water based drilling fluid. Properties: MD Density Viscosity Plastic Viscosity Yield Point pH API Fluid Loss 8600' - 11000' 9.5-11 . 40-53 15-25 15-25 8.5-9.5 System Formulation: 6% KCI / EZ Mud DP Product Concentration Water 0.905 bbl KC1 22 ppb (29 K chlorides) Caustic 0.2 ppb (9 pH) BARAZAN D+ 1.25 ppb (as required 18 YP) EZ MUD DP 0.75 ppb(initially 0.25 ppb) DEXTRID LT 1-2 ppb PAC-L 1 ppb BARACARB 5/25/50 10-20 ppb BAROTROL PLUS 2 ppb SOLTEX 2 ppb(if needed) BAROID 41 as required for a 9.5—10.5 ppg ALDACIDE G 0.1 ppb BARACOR 700 1 ppb BARASCAV D 0.5 ppb (maintain per dilution rate) 11.2 Program mud weights are generated by reviewing data from producing & shut in offset wells, estimated BHP's from formations capable of producing fluids or gas and formations which could require mud weights for hole stabilization. 11.3 A guiding philosophy will be that it is less risky to weight up a lower weight mud than be overbalanced and have the challenge to mitigate lost circulation while drilling ahead. Page 13 Revision 0 October, 2014 SCU 41 B-04 H Drilling Procedure Rev 0 Ililrorp Alaska,i.l.0 12.0 Whipstock Running Procedure 12.1 M/U window milling assembly and TIH w/4-1/2"DP off of pipe rack. • Use a 6"taper mill and a 6" string mill above to ensure whipstock assy will pass freely. • Ensure BHA components have been inspected previously. • Caliper and drift all BHA components before running them in the hole. • Drift DP prior to RIH. • Lightly wash and ream any tight spots noted. 12.2 TIH to CIBP (8650' MD). Note that this was a wireline measurement so actual depth tagged may vary slightly. Keep up with the #of joints picked up so we know where we are. 12.3 Pressure test casing to 2500 psi/ 30 min. Chart record casing test& keep track of the amount of fluid pumped. Stage up to 2500 psi in 500 psi increments. 12.4 CBU &circ at least (1) hi-vis sweep to remove any debris created by the clean out run. Anything left in the wellbore could affect the setting of the Whipstock. 12.5 TOH. 12.6 Make up mills on a joint of HWDP. 12.7 RIH & set in slips. 12.8 Make up float sub, install float. 12.9 Make up UBHO sub. 12.10 Orient UBHO to starter mill. 12.11 Leave assembly hanging in the elevators, and stand back on floor. 12.12 Bring Whipstock to rig floor on the pipe skate. Do not slam into bottom of Whipstock with pipe skate. 12.13 Pick up Whipstock per Baker rep using the Baker Whipstock handling system using air hoist. Allow assy to hang while Baker Rep inspects and removes shear screws as needed and any safety screws. Note: Anchor should be pinned with 6 shear screws initially. Shear screws are rated for 6,630 lbs each. REMOVE 3 screws for a set down shear of 6,630 x 3=19,890 lbs. Page 14 Revision 0 October, 2014 SCU 41B-04 Drilling Procedure Rev 0 Ililcorp Alaska,LLC Note: Attach mills to Whipstock with (1)35k mill shear bolt. 12.14 If needed, open BOP Blinds. 12.15 Run the Whipstock in the hole, install safety clamp as per Baker Rep, and install hole cover wrap. 12.16 Release pick up system at this point, Make up mills. 12.17 With the top drive, pick the assembly and position the starting mill to align with the hole in the slide. The Baker Rep will instruct the driller when the slot is lined up,the shear bolt then can be made up by the Baker Rep. 12.18 The assembly can now be picked up to ensure that the shear bolt is tight. 12.19 Remove the handling system. 12.20 Slowly run in the hole as per Baker Rep. Run extremely slow through the BOP &wear bushing. 12.21 Run in hole at 1 V2 to 2 minutes per stand. 12.22 Fill every 30 stands or as needed, do not rotate or work the string unnecessarily. 12.23 Call for Baker Rep. 15— 10 stands before getting to bottom. 12.24 Orient at least 30' —45' above the CIBP. Ensure to have gyro personnel and equipment as well as a wireline unit R/U and ready. Page 15 Revision 0 October, 2014 SCU 41B-04 Drilling Procedure Rev 0 Iiileorp Alaska,IAA: WindowMaster G2 System on TorqueMaster BTA 7"29.7#Csg—WindowMaster G2 On BTA IBHA#1 Connection Length O.D.. BOTTOM TRIP ANCHOR 3%IF-Box X Bottom Guide 3.21' 6.18" WINDOW MASTER WHIPSTOCK Shear Bolt X 3'A IF-Pin 14.6' 6.00" WINDOW MILL 3-1/2 Reg-Pin X Mill 1.5' 6.63" LOWER WATER MELON MILL 3-1/2 IF-Box X 3-1/2 Reg-Box 5.5' 6.50" FLEX JOINT 3-1/2 IF-Box X 3-1/2 IF-Pin 6.6' 4.75" UPPER WATER MELON MILL 3-1/2 IF-Box X 3-1/2 IF-Pin 5.8' 6.63" 1 JT HWDP 3-1/2 IF-Box X 3-1/2 IF-Pin 30' 5.25" MWD Survey Tool 3-1/2 IF-Box X 3-1/2 IF-Pin 3' 4.75" UBHO 3-1/2 IF-Box X 3-1/2 IF-Pin 3' 4.75" Bowen Lubricated Bumper Jar 3-1/2 IF-Box X 3-1/2 IF-Pin 15' 4.75" 6 DRILL COLLARS 3-1/2 IF-Box X 3-1/2 IF-Pin 180' 4.75" 30 JTS—HWDP 4-1/2 CDS40 Box X 4-1/2 CDS40-Pin 900' 4.75" CONNECTIONS ON TUBULARS ARE SUBJECT TO CHANGE. BHA'S SHOW SPECIFIC CONNECTIONS AS AN EXAMPLE ONLY Page 16 Revision 0 October, 2014 SCU 41 B-04 H Drilling Procedure Rev 0 lliknrp Alaska,1.1.1: 13.0 Whipstock Setting Procedure 13.1 With the bottom of the Whipstock 30—45' above the CIBP, measure and record P/U and S/O weights. We will orient Whipstock face using Gyrodata. Ensure that UBHO and gyro tool mate up properly before making up UBHO sub. 13.2 Orient Whipstock to desired direction by turning DP in '/4 round increments. P/U and S/O on DP to work all torque out (Being careful not to set BTA). Whipstock Orientation Diagram: 30 AZI (... 80 AZI Desired orientation of the Whipstock face is in 30 to 80 degrees azimuth. Hole Angle at window interval (8600' MD) is < 1 deg. The wellbore trajectory is also planned to 77 to 8 degrees azimuth. Highside of the casing at 8600' is negligible. 13.3 Once Whipstock is in desired orientation, slack off and tag CIBP to set Bottom Trip Anchor. 13.4 Set down 12-15K on anchor to trip, P/U 5-7K maximum overpull to verify anchor is set. The window mill can then be sheared off by slacking off weight on the Whipstock shear bolt. (25k shear value). 13.5 P/U 5-10' above top of Whipstock. 13.6 Displace to 9.5 ppg 6% KCl/PHPA drilling fluid. 13.7 Record P/U, S/O weights, and free rotation. Slack off to top of whipstock and with light weight and low torque. Mill window. Utilize 4 ditch magnets on the surface to catch metal cuttings. 13.8 Install catch trays in shaker underflow chute to help catch iron. 13.9 Keep iron in separate bbls. Record weight of iron recovered on ditch magnets. Page 17 Revision 0 October, 2014 SCU 41B-04 Drilling Procedure Rev 0 Ililrnrp Alaska.1.I.1: 13.10 Estimated metal cuttings volume from cutting window: 7" e;f 29.7# N-80 Cuttings Weight Window Length Casing Weight Min (lbs) Avg(lbs) Max(lbs) 13 29.7# 80 110 140 13.11 Drill approx. 20' rat hole to accommodate the drilling assembly. Ream window as needed to assure there is little or no drag. After reaming, shut off pumps and rotary (if hole conditions allow) and pass through window checking for drag. V 13.12 Circulate Bottoms Up until MW in= MW out. 411-LA"/ r<9 13.13 Conduct FIT to 12.5 ppg EMW. • (12.5 —9.5) * 0.052 * 8600' tvd= 1342 psi -x 1`i—177 Note: Offset field test data predicts frac gradients at the window to be between 12 ppg and 15 ppg. A 12.5 ppg FIT results in a 2 ppg kick margin while drilling the interval with a 10.5 ppg fluid density. 13.14 Slug pipe and POOH. Gauge Mills for wear. 13.15 Should a second run be required pick up the following BHA. Back Up Mills Connection Length O.D. WINDOW MILL 3 '/ REG-P X MILL 0.98 6.63 NEW LOWER WATERMELON MILL 3 '/2 IF-B X 3 '/2 REG-B 5.5 6.5 FLEX JOINT 3 '/ IF-B X 3 '/2 IF-P 6.5 4.75 UPPER WATERMELON MILL 3 '/2" IF-B X 3 '/2" IF-P 5.83 6.63 FLOAT SUB 3 '/" IF-B X 3 '/2" IF-P 3.00 4.75 XO sub and 30 jts-HWDP 4 '/" CDS40-B X 3 W IF-P 900' 5.25 CONNECTIONS ON TUBULARS ARE SUBJECT TO CHANGE. BHA'S SHOW SPECIFIC CONNECTIONS AS AN EXAMPLE ONLY! Page 18 Revision 0 October, 2014 SCU 41 B-04 14Drilling Procedure Rev 0 Ilileorp Alaska,1.1,C 14.0 Drill 6" Hole Section 14.1 P/U 6" directional drilling assy. 14.2 Ensure BHA Components have been inspected previously. 14.3 Drift & caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. 14.4 Ensure TF offset is measured accurately and entered correctly into the MWD software. 14.5 Confirm that the bit is dressed with a TFA of 0.46 —0.56 sqin. Have DD run hydraulics models to ensure optimum TFA. We want to pump at 150 - 250 gpm. 14.6 Motor AKO should be set at 1.2 deg. Must keep up with 4 deg/100 DLS in the build section of - the wellbore. 14.7 Primary bit will be the HDBS 6" MM55 PDC bit. Ensure to have a back up bit available on - location. Page 19 Revision 0 October, 2014 SCU 41B-04 Drilling Procedure Rev 0 Ilil•orp Ia.ka. 6" (152mm) MM55 PRODUCT SPECIFICATIONS Cutter Type SelectCutter IADC Code M424 Body Type MATRIX . Total Cutter Count Cutter Distribution 4 . Face 18 Gauge 6 Number of Large Nozzles 0 Number of Medium Nozzles 0 Number of Small Nozzles 5 a,. gin. Number of Micro Nozzles 0 Number of Ports(Size) 0 Number of Replaceable Ports(Size i 0 ; Junk Slot Area Isq in) 6.18 E; • Normalized Face Volume 30.47% API Connection 3-1;2 REG.PIN Recommended Make-Up Torque* 5,173—7.665 Ft*lbs. 44. Nominal Dimensions** Make-Up Face to Nose 9.26 in-235 mm Gauge Length 2 in-51 mm Sleeve Length 0 in-0 mm Shank Diameter 4.5 in-114 mm � Break Out Plate(Mat.4/Legacy4) 181953144030 Approximate Shipping VI eight SOLbs.-36Kg. SPECIAL FF TURES 1132"Relieved Gage Material 4771781 '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.V8.2. "Design dimensions arc nominal and may vary slightly on manufactured product.Halliburton Dnll Sits and Services models arc continuously reviewed and refined. Product specifications may change without notice. C 2014 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. www.halliburtoa.com Page 20 Revision 0 October, 2014 SCU 41B-04 Drilling Procedure Rev 0 ilileorp Alaska,I.I.0 14.8 TIH to window. Shallow test MWD on trip in. 14.9 TIH through window, ensure Halliburton MWD service rep on rig floor during this operation. • Do not rotate string while bit is across face of Whipstock. 14.10 Drill 6"hole to 11000' MD using motor assembly. ' • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Utilize ECD while pumping to minimize waterflow from Tyonek sands • On trips spot weighted pills inside window and hi vis pills at TD to control waterflow • Try to keep waterflow below 10 bph while tripping • 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. • See attached mud program for hole cleaning and LCM strategies. • Ensure solids control equipment functioning properly and utilized to keep LGS to a minimum without excessive dilution. • Adjust MW as necessary to maintain hole stability. . • Ensure mud engineer set up to perform HTHP fluid loss. • Maintain API fluid loss < 6. • Take MWD surveys every stand drilled. • Minimize backreaming when working tight hole 14.11 Hilcorp Geologists will follow mud log closely to determine exact TD. 14.12 At TD pump a sweep and a marker to be used as a fluid caliper to determine annulus volume for cement calculations. CBU, and pull a wiper trip back to the window. 14.13 TOH with drilling assembly, handle BHA as appropriate. Page 21 Revision 0 October, 2014 SCU 41 B-04 Drilling Procedure Rev 0 IIilrnrp Ala.ka.iii: 15.0 Run 4.5" Production Casing 15.1 R/U Weatherford 4.5" casing running equipment. • Ensure 4.5" DWC/C x 4-1/2" CDS-40 crossover on rig floor and M/U to FOSV. • R/U fill up line to fill casing while running. • Ensure all casing has been drifted and tally verified prior to running. • Be sure to count the total# of joints 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. 15.2 P/U shoe joint, visually verify no debris inside joint. 15.3 Continue M/U &thread locking shoe track assy consisting of: • (1) Shoe joint w/ shoe bucked on&threadlocked(coupling also thread locked). • (1) Baker locked joint. • (1) Joint with float collar bucked on pin end &threadlocked (coupling also thread locked). • (1) Joint with landing collar bucked up. • Solid body centralizers will be pre-installed on shoe joint, FC joint, and LC joint. • Install solid body centralizers (Volant), one per joint, and leave centralizers free floating so that they can slide up and down the joint. • Ensure proper operation of float shoe &FC. 15.4 Continue running 4.5" production casing • Fill casing while running using fill up line on rig floor. • Use "API Modified"thread compound. Dope pin end only w/paint brush. • Install solid body centralizers on every other joint to window. Leave the centralizers free floating. • Utilize a collar clamp until weight is sufficient to keep slips set properly. 4.5" DWC/C HT M/U torques Casing OD Minimum Maximum Yield Torque 4-1/2" 5800 ft-lbs 6500 ft-lbs 7200 ft-lbs Page 22 Revision 0 October, 2014 SCU 41 B-04 Drilling Procedure Rev 0 tJitrnrp Alaska. Technical Specifications Connection Type: Size(O.D.): Weight(Wall): Grade: DWC/C Tubing 4-1/2 in 12.60 lb/ft(0.271 in) L-80 standard Material L-80 Grade 80,000 Minimum Yield Strength (psi) 111111.1111111111111.1111W tJ SA 95,000 Minimum Ultimate Strength (psi) VAM USA 4424 W.Sam Houston Pkwy.Suite 150 Pipe Dimensions Houston.TX 77041 4.500 Nominal Pipe Body O.D. (in) Fax713-479-3234ne:713-479-3200 3.958 Nominal Pipe Body I.D.(in) E-mail:VAMUSAsalesayam-usa.com 0.271 Nominal Wall Thickness(in) 12.60 Nominal Weight(Ibsfft) 12.25 Plain End Weight(lbs/ft) 3.600 Nominal Pipe Body Area (sq in) Pipe Body Performance Properties 288.000 Minimum Pipe Body Yield Strength (lbs) 7.500 Minimum Collapse Pressure(psi) 8,430 Minimum Internal Yield Pressure(psi) 7.700 Hydrostatic Test Pressure (psi) Connection Dimensions 5.000 Connection O.D. (in) 3.958 Connection I.D. (in) 3.833 Connection Drift Diameter(in) 3.94 Make-up Loss (in) 3.600 Critical Area (sq in) 100.0 Joint Efficiency(%) Connection Performance Properties 288,000 Joint Strength (lbs) 14,290 Reference String Length (ft) 1.6 Design Factor 314,000 API Joint Strength (lbs) 288.000 Compression Rating (lbs) 7.500 API Collapse Pressure Rating (psi) 8.430 API Internal Pressure Resistance(psi) 81.5 Maximum Uniaxial Bend Rating [degrees/100 ft] Appoximated Field End Torque Values 5,800 Minimum Final Torque (ft-lbs) 6,500 Maximum Final Torque(ft-lbs) 7,200 Connection Yield Torque (ft-lbs) Page 23 Revision 0 October, 2014 SCU 41B-04 Drilling Procedure Rev 0 l7ilrorp Alaska,IJd: 15.7 Ensure to run enough liner to provide for approx 200' overlap inside 7" casing. Ensure hanger/pkr will not be set in a 7" connection. 15.8 Before picking up Baker ZXP liner hanger/packer assy, count the#of joints on the pipe deck to . make sure it coincides with the pipe tally. 15.9 M/U Baker ZXP liner top packer. Fill liner tieback sleeve with"Pal mix", ensure mixture is thin , enough to travel past the HRD tool and down to the packoff. Wait 30 min for mixture to set up. 15.10 RIH one stand and circulate a minimum of one liner volume. Note weight of liner. 15.11 RIH w/liner on DP no faster than 1 min/ stand. Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 15.12 M/U top drive and fill pipe while lowering string every 10 stands. 15.13 Set slowly in and pull slowly out of slips. 15.14 Circulate 1-1/2 drill pipe and liner volume at 7" window prior to going into open hole. Stage pumps up slowly and monitor for losses. Do not exceed 60% of the nominal liner hanger setting pressure. 15.15 Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10, 20, & 30 rpm. 15.16 Continue to fill the string every 10 joints while running liner in open hole. Do not stop to fill casing. 15.17 P/U the cmt stand and tag bottom with the liner shoe. P/U 2' off bottom. Note slack-off and pick-up weights. Record rotating torque values at 10, 20, & 30 rpm. 15.18 Stage pump rates up slowly to circulating rate without exceeding 60% of the liner hanger setting pressure. Circ and condition mud with the liner on bottom. Reduce the low end rheology of the drilling fluid by adding water and thinners. 15.19 Reciprocate&rotate string if hole conditions allow. Circ until hole and mud is in good condition for cementing. Page 24 Revision 0 October, 2014 SCU 41 B-04 Drilling Procedure Rev 0 flilearp Alaska,LIA 16.0 Cement 4.5" Production Casing • Cement will be mixed using batch mixer to ensure consistent density 16.1 Hold a pre-job safety meeting over the upcoming cmt operations. 16.2 Attempt to reciprocate the casing during cmt operations until hole gets sticky. 16.3 Pump 5 bbls 12.5 ppg MUDPUSH II spacer. 16.4 Test surface cmt lines to 4500 psi. 16.5 Pump remaining 10 bbls 12.5 ppg MUDPUSH II spacer. 16.6 Mix and pump 65 bbls of 15.3 ppg class "G" cmt per below recipe with 2 lbs/bbl of Cemnet or equivalent loss circulation fiber. Ensure cmt is pumped at designed weight. Job is designed to pump 50% OH excess but if fluid caliper dictates otherwise we may increase excess volumes. Cement volume is designed to give 500' of cement inside window in annulus between 7" casing and 4-1/2" casing. Est TOC 8400' TMD. Gk-- 16.7 Displacement fluid will be produced water or 3%KCL. —153 bbls of displacement fluid Cement Calculations 7"x 4-1/2 DP"Overlap: (8405' — 8105') x 0.017 = 5.1 bbls 7"x 4-1/2" Liner Overlap: (8605' — 8405') x 0.017 = 3.4 bbls 6"OH x 4-1/2"Liner: (11000' — 8605') x 0.0153 x 1.5 = 54.9 bbls Shoe Track: 80' x 0.01522 = 1.2 bbls Total Volume(bbls): 5.1 + 3.4 +54.9 + 1.2= 65 bbls Total Volume(ft3): 65 bbls x 5.615 ft3/bbl = 363 ft3 Total Volume(sx): 363 ft3 / 1.35 ft3/sk= 269 sx✓ O �`` Page 25 Revision 0 October, 2014 SCU 41 B-04 Drilling Procedure Rev 0 Ilik orp Ala.ka,MA: Slurry Information: System Easy BLOK Density 15.3 lb/'.1 Yield 1.34 ft3/sk✓ Mixed Water 5. "' gal/sk Mixed Fluid 5.879 gal/sk Expected Thickening 70 Bc at 05:00 hr:mn API Fluid Loss <25 mL in 30.0 min at 155degF/ 1000 psi Code Description Concentration G Cement 94 lb/sk D046 Anti Foam 0.2% BWOC Additives D202 Dispersant 1.5% BWOC D400 Gas Control Agent 0.8% BWOC D154 Extender 8.0% BWOC 16.8 Drop DP dart and displace with 8.6 ppg produced water. 16.9 Pump cement at max rate of 8 bbl/min. Reduce pump rate to 3 bpm prior to latching DP dart into liner wiper plug. Note plug departure from liner hanger running tool and resume pumping at full displacement rate. Displacement volume can be re-zeroed at this point 16.10 If elevated displacement pressures are encountered,position liner at setting depth and cease reciprocation. Monitor returns&pressure closely while circulating. Notify Drilling Foreman immediately of any changes. Reduce pump rate as required to avoid packoff. 16.11 Bump the plug and pressure up to up as required by Baker procedure to set the liner hanger(15% above nominal setting pressure. Hold pressure for 3-5 minutes. 16.12 Slack off total liner weight plus 30k to confirm hanger is set. 16.13 Do not overdisplace by more than 1/2 shoe track (-1 bbls). Shoe track volume is 1.8 bbls. 16.14 Pressure up to 4200 psi to release the running tool (HRD-E) from the liner Page 26 Revision 0 October, 2014 SCU 41B-04 in Drilling Procedure Rev 0 Ililear,Alaska,liC 16.15 Bleed pressure to zero to check float equipment. 16.16 P/U, verify setting tool is released, and expose setting dogs on top of tieback sleeve 16.17 Rotate slowly and slack off 50k downhole to set ZXPN. 16.18 Pressure up drill pipe to 500 psi and pick up to remove the RS packoff bushing from the RS nipple. Bump up pressure as req'd to maintain 500 psi DP pressure while moving pipe until the pressure drops rapidly, indicating pack-off is above the sealing area (ensure that 500 psi will be enough to overcome hydrostatic differential at liner top). 16.19 Immediately with the loss of pressure and before DP reaches zero, initiate circulation while picking up to position the bottom of the stinger inside the tieback sleeve. Increase pump rate to wellbore clean up rate until the sleeve area is thoroughly cleaned. 16.20 Pick up to the high-rate circulation point above the tieback extension, mark the pipe for reciprocation, do not re-tag the liner top, and circulate the well clean. 16.21 Watch for cement returns and record the estimated volume. Rotate & circulate to clear cmt from DP. 16.22 POOH, LDDP. Verify the liner top packer received the required setting force by inspecting the rotating dog sub. Backup release from liner hanger: 16.23 If the HRD-E tool still does not release hydraulically, left-hand (counterclockwise) torque will have to be applied to the tool. This torque acts to shear brass screws. Bleed off pump pressure and ensure that the tool is in the neutral position. Apply left-hand torque as required to shear screws. 16.24 NOTE: Some hole conditions may require movement of the drillpipe to "work"the torque down to the setting tool. 16.25 After screws have sheared, the top sub and body of the setting tool will turn 1/4 turn. Then proceed slacking off set-down weight to shear second set of shear screws. The top sub will drop 1-3/4 inches. At this point, the bottom sub no longer supports the collet fingers. Pick straight up with workstring to release collet from the profile. Page 27 Revision 0 October, 2014 SCU 41B-04 H Drilling Procedure Rev 0 Ili!carp Alaska,1.1.1: 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 • Pump rate while displacing, note whether displacement by pump truck or mud pumps,weight&type of displacing fluid • Note if casing is reciprocated or rotated during the job • Calculated volume of displacement,actual displacement volume, whether plug bumped&bump pressure, do floats hold • Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure / • Note if pre flush or cement returns at surface& volume • Note time cement in place • Note calculated top of cement • Add any comments which would describe the success or problems during the cement job Note: Send Csg & cmt report+ "As-Run"liner tally to mmvers(&hilcorp.com 17.0 RDMO 17.1 Install BPV in wellhead. RILDs. 17.2 Proceed to completion procedure /Q7 4/4 . Cf�4.— frt < < c.c.s;7it, 3 a a 0 pS c. et C7YXL(J csc: 7e4l/•N•t q t Page 28 Revision 0 October, 2014 SCU 41 B-04 H Drilling Procedure Rev 0 liileorp Alaska,LLC 18.0 BOP Schematic iii cif it! !El rill iii iii ria ______________j 3.5" [5 P.i c d r^.:,Ct t 3 i#i.iil llll:ilil ili Z % S ° VL? 3.00' �, t ,, IL r.._ �,i- r “, 8L Its' -- / 1t/13 4,d, ,.. �� .' ill lii iii lei iii _ illlt ,, la�al !tl 1I( Z1Ii • 2 1/15 5M Kill Side ��°` �3 1/8 5M Choke Side 1.41' _....' i.a 1 rJ 11 1417;x? .2X J « V6� ice. �♦liT nu lei ti l• III Grade fel_lei III fti oat 4____________--(4 t ill 19 C. .i mi /! y/K A mat 'ism INN .l 20" ' 5/8" Page 29 Revision 0 October, 2014 SCU 41B-04 int Drilling Procedure Rev 0 11 ilrarp:Ua'ka.1.1,1 19.0 Wellhead Schematic BHTA,Bowen,3 118 5M FE tll.',,.�- ill, IMMINIEW Valve,swab,VG-M, ,.. 31/85M FE, HWO ° Valve,Wing,VG-M, Valve,Wing,SSV, .,cls 1c" 3 1/8 5M FE, HWO VG-M,3118 5M FE Qty 2 w/Halliburton Si p Hydraulic operator Valve,Wing,VGh,1. ,� ° 21/16 5M FE, HWO14,!.9/',,!;„44‘'i13( ' i I ',„, ,r tit ;' ll0P5+111 Valve,upper master. ( l4 VG-M,3118 5M FE, t1` ,: HWO ;� ,. mow Valve,master,VG-M, ," 3118 5M FE,HWO 4v` 46 Adapter,Seaboard SM-E-CLN , 71/16 5M stdd X 31/8 5M stdd top,w1'/i npt control tine exit ,, $d Ps Tbg head,Seaboard,S-8; .� - — Ground level 13 5/8 3M X 71/16"5M. ! ~•' w/2-211165MSSO lta el i �AI r es) Valve,Seaboard, i 'I' 2 1116 5M FE,HWO,Qty 2 t fik * s it iit tit I oil ,.. "` , Valve.Seaboard,2" LP Ill'p `' )'. e-i. ill mow Page 30 Revision 0 October, 2014 SCU 41B-04 Drilling Procedure Rev 0 Ilileorp:Ua.ka, 20.0 Days vs Depth Days Vs Depth 0 SCU 4113-04(SCU 41A-04 ST) 2000 4000 S 6000 N 8000 10000 • 12000 1 I 0 2 4 6 8 10 12 14 16 18 20 Days Page 31 Revision 0 October, 2014 SCU 41 B-04 Li Drilling Procedure Rev 0 I lilrorp Ua=ka.I.1.1: 21.0 Geo-Prog GEOLOGICAL PROGNOSIS WELL NAME: SCU 41B-04 aka 41A-04ST FIELD: Swanson River SCU 41A-04 Pa, SURFACEX 346506 30 STATE Alaska SURFACE Y 2460223 80 ! 1 1 BOTTOM HOLE X 346608.56 TVD REF DATUM KB BOTTOM HOLEY 2460805.18 TVD REF ELEV 192 18'KB(Saxon 169) I. COORDREF SYSTEM NAD27 IGROUNDELEV 173.4 PROPOSED TD. 11000.00 MD PROPOSED TD 10874,94 TVD i A sidetrack well out of the SCU 41A-04 to test the H1-8 benches. The well will offest the successful SCU Objective. 44-33 updip of the current takepoint. I i Geo Summary/ Based on subsurface evaluation Justification: I I ANTICIPATED FORMATION TOPS& GEOHAZARDS EXPECTED TOP witiOLLFormation FORMATION FLUID MD_ TVD Est Pressure X Y +/- KOP 8600 8600 346513.5 2460213.0 HP-H20_SANDf., Wet Sand Water 8921 8918 4300-4900# 346528.9 2460246.7 20 r BSE_HP H20_KRE_GRID Wet Sand Water 9160 9142 4300-4900# 346543.2 2460327.5 20 SR_H1ST Hemlock Oil Oil 10402 10277 1000-1400# 346605.4 2460788.8 20 SR_H5ST Hemlock Oil Oil 10588 10463 1200-2800# 346606.3 2460793.9 20 SR_H7ST Hemlock Oil Oil 10694 10569 1200-2800# 346606 7 2460796.9 20 , SR H10ST Hemlock Oil Oil 10825 ( 10700 1200-2800# 346607 3 2460800.5 20 TD 11000 10875 346608.6 2460805.2 Primary Objective =Secondary Objective TARGET RADIUS 50 FT @ the Hemlock level i DATA COLLECTION REQUIREMENTS: Mud Logging: Full crew of4 from KOP. LVW Data: Triple Combo LWD on Production hole section E-Line Log Data: 1 i COMPLETION TYPE Gas lift completion ANTICIPATED RATES 2000 bpd gross fluid ! 1_ ARTIFICIAL LIFT EQUIPMENT OD I s L, TUBING SIZE 2 7/8"or 3.5" OTHER COMMENTS / . i 4 i Offset wells have seen water flows and lost circulation in the lower Tyonek! ✓ 1 We be be kicking off above the high pressured water sand and will encounter it in the well ., Page 32 Revision 0 October, 2014 SCU 41 B-04 Drilling Procedure Rev 0 1likorp Aluska,!LC 22.0 Anticipated Drilling Hazards Water Flow: ✓ r The Tyonek water sands will be open. Ensure to treat the initial flow as gas. After we are confident we are only dealing with water from the sands we will drill the interval while the well is flowing water. Utilize MW and ECD to keep the well dead will drilling. During trips we will use heavy pills and viscous pills to control the flow and trip in and out of the well. Lost Circulation: Ensure 500 lbs of medium/coarse fibrous material, 500 lbs SteelSeal (Angular, dual-composition carbon-based material), & 500 lbs different sizes of Calcium Carbonate are available on location to mix LCM pills at moderate product concentrations. Hole Cleaning: Maintain rheology w/viscofier as necessary. Sweep hole w/20 bbls flowzan as necessary. Optimize solids control equipment to maintain density and minimize sand content. Maintain programmed mud specs. 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. • Increase fluid density as required to control running coals. • Emphasize good hole cleaning through hydraulics, ROP and system rheology. • Minimize swab and surge pressures • Minimize back reaming through coals when possible H2S: H2S is not present in this hole section. No abnormal temperatures or pressures are present in this hole section. Page 33 Revision 0 October, 2014 SCU 41 B-04 H Drilling Procedure Rev 0 Ilileorp Alaska,1.11A: 23.0 Rig Layout 1iI mil 1:0I'-:‘11 t 7 r f I usimmot 111 i . ,,i:;' . r I i i - l'-'11 ' .- ' ' " i 11.11 3.111i;- :a'llitillilli," unauuu:� ;�• _• =r'11 i.1. r-- ,,._;. I!!! Ill!.;, I •iglu. x l __. I �"'IIICIIII� n� y i �li'.iall :! :JI m !ion � Imam 11 ^.I;: • 11I�1 I�It=7 _ I_[ • 7i -,_ iIII iii_p _ In r 1Aviv' ' .. !!■III■IL I I lei�DII uHi 7111 -�'' I�_ul�r-I'I� 111111 III y,.� BIIII 11.......1 1' I 11111 I �� i 1 ;z�: "1 _int Y" m !Il!lilillilli 1 1 JI IN II 11111111,I I I I I I IIIS ;IG ' , 1111111111.I1,!IliVIIIIIIIIII. I I........II1.............. SMI l . - - n e I < , Ii_ I I ILU Ir D d a Page 34 Revision 0 October, 2014 SCU 41 B-04 H Drilling Procedure Rev 0 Ililrnrp Alaska,LLC 24.0 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 35 Revision 0 October, 2014 SCU 41 B-04 H Drilling Procedure Rev 0 nikorp Alaska.i.i.l. 25.0 Choke Manifold Schematic f/ (,:' `' ! 87.24 j 43.62 43.62 N 15171.1 V • r if„1 � �T •, I-,8.43 14.62 '- 1462 18.434'VO0)' -0.19 0.19 • ' 0.19 0.19-- '.��y/ 0 Z 0.19 �. 0.19 'VS= 4911- A JC 1. 9�i i II i Y 0.19 i . t.,:7:::::N!! ►I INNI�� �1/41..1 -7, /`fi e 1 9.1100 A V4,11 . �' '1 0.19 -� til\1,1.11 11111q1,0.19^ I `' 0. 0.19-1 1 7.84 .�� .. ® Q' \::7 �l i 9.84 70 imi MXr 7.M r0.19 � I.It 1.1 1\I I.1 I ( I I Oum , C 0.193 36.0] '�` qI1 a19-1 '1p) ,� X03 14.62 ��il,. ���i _ 4r ,-1 14.87 �Ry% 16.62 'l'm f1 0 ����j a i { I m m 'iru o19 e ,,,,,,,/ L 10.50 ,? �, ' r L 10.50 ii ll • rim � r uu61 q. -0.19 .. U Al /D CHOKE 112.011:(EY -0.19 -0.19 0.19 - MANUAL ACIOAIID .11188.881. 0.19-- --0.19 ORERAION // -6.31--1482--14.82 ----14.82 14.82 -13.31* 'F,.t, 43.62 43.62 PO 1.40<j, 87.24 [@ r kr.x't- CAD -t-E- �� r 'r��.C..:�• Llex 1.LAYOUT M1N R GASKET 1 ....,,,,,,r_ � '0o.,,,u„, I �_ � Ci ur4a .. �' _ _ _.. ' s" 'u,,... .�un7 ammo • ..._ , 4-- ..ur 7. .`.a:;aur w+ z i-.n4•rr s000 w9l ��� 1,..S. Page 36 Revision 0 October, 2014 SCU 41 B-04 Drilling Procedure Rev 0 llilcnrp Alaxka,IAA: 26.0 Casing Design Information Calculation & Casing Design Factors Swanson River Unit DATE: 10/20/2014 WELL:SCU 41B-04(SCU 41A-04 ST) FIELD: Soldotna Creek Unit DESIGN BY:Monty M Myers Design Criteria: Hole Size Mud Density: Hole Size 6" Mud Density: 10.5 ppg Hole Size Mud Density: Drilling Mode MASP: 1739 psi(See attached MASP determination&calculation) Production Mode MASP: 2827 psi (See attached MASP determination& calculation) Collapse Calculation: Section Calculation 1, 2 Normal gradient external stress (0.406 psi/ft)and the casing evacuated for the internal stress Casing Section Calculation/Specification 1 2 3 4 Casing OD 4-1/2" Top(MD) 8,400 Top(TVD) 8,400 Bottom (MD) 11,000 Bottom (TVD) 10,875 Length 2,600 Weight(ppf) 12.6 Grade L-80 Connection DWC/C Weight w/o Bouyancy Factor(lbs) 32,760 Tension at Top of Section (lbs) 32,760 Min strength Tension (1000 lbs) 288 Worst Case Safety Factor(Tension) 8.79 Collapse Pressure at bottom(Psi) 4,415 Collapse Resistance w/o tension(Psi) 7,500 Worst Case Safety Factor(Collapse) 1.70 MASP (psi) 1,739 Minimum Yield(psi) 8,430 Worst case safety factor(Burst) 4.85 Page 37 Revision 0 October, 2014 SCU 41B-04 Drilling Procedure Rev 0 lrilrnrp AlaRka,LLC 27.0 6" Hole Section MASP II Maximum Anticipated Surface Pressure Calculation 6"Hole Section Hilcorp SCU 41B-04 Kenai,Alaska MD ND Planned Top: 0 0 Planned TD: 11000 10875 Anticipated Formations and Pressures: Formation ND Est Pressure Oil/Gas/Wet PPG Grad HP-H20_SAND 8,918 4850 WATER 10.5 0.544 BSE_HP-H20_KRE 9,142 4900 WATER 10.3 0.536 obei-x SR_H 1ST 10,277 1400 OIL 2.6 0.136 �'� w SR_H5ST 10,463 2800 OIL 5.1 0.268 L/eco F) SR_H7ST 10,569 2800 OIL 5.1 0.265 i— SR_H1OST 10,700 2800 OIL 5.0 0.262 TD 11,000 2800 OIL 4.9 0.255 //•y!N Offset Well Mud Densities Well MW range Top(ND) Bottom(ND) Date SCU 44-05 9.8-lOppg 9,400 10,925 2014 SCU 21-4 12 ppg 0 10,965 1961 SCU 44-33 11.3-12.5 ppg 9,216 10,747 2013 SCU 41A-4 11.2 ppg 9,300 10,807 2013 Assumptions: 1. Maximum planned mud density for the 6"hole section is 10.5 ppg. 2. Calculations assume reservoirs contain 100%gas(worst case). 3. Calculations assume worst case event is complete evacuation of wellbore to gas. 4. Anticipated fracture gradient at 8600'ND=12.5 ppg EMW Fracture Pressure at 6"window considering a full column of gas from window to surface: 8600(ft)x 0.65(psi/ft)= 5590 5590(psi)-[0.1(psi/ft)*8600(ft)]= 4730 psi MASP from pore pressure;entire wellbore evacuated to gas from TD 10875(ft)x 0.26(psi/ft)= 2827 psi 2827(psi)-[0.1(psi/ft)*10875(ft)]= 1739 psi Summary: 1. MASP while drilling 6-1/8"production hole is governed by SIBHP minus entire wellbore evacuated to gas from TD. 2. MASP during production mode is governed by SIBHP minus entire wellbore evacuated to gas from TD. Page 38 Revision 0 October, 2014 HSCIJ41B-04 Drilling Procedure Rev 0 nileorp Alak:,.1.1,1: 28.0 Plot (NAD 27) (Governmental Sections) A028406 SCU_43A-33 r1411 SCU_343-33 BHLTT,// A028399 1CU_13.34 BHLt S008N009W es " , I.-- Bg • ' A02899d r a)� I ,,, SCU_33-33 HL• i � r ,r''� J X14-1. +*•„.•-'''''''------""''---t., — -••�� �``�1 SRU_24-33 26-33 am* Salt 44B-33 BHL•`-'µ�� SCU_44 3,.BHL• r .- - SCU BI-IL ✓ so:41B-104TPII SCU_2t-04 BH SCU21A-04 SHL • I i • scu_341-04 BHL.----SCIS-lI B-04 SHL] tgni jSCU_41A-04 SAL. I r ` 1 SCU_42-Lt!BHL1 / 11 // SCU_12A-0 BHL• I / fiC U_12-G3 SHL•"^ SCU_22B-04 BHLti / SCU_332-04 BHL• SCU_22-04PB BHL• A028997 scu_22-04 BHL} + © SGU_23B 03 BHLj GU_23A-03 BM. SO07N009W n • SCU23-C3 B4I ,% SCU=13-04 eHle"-• -^t /// _• 1 • '~~ SCU_43A-04 BHL• SCU_43-03 BH.Lt- Legend • Other Surface Well Locations SCU 44-04 BHL • Other Bottom Hole Locations 15CU_314-04 BHL ---- Well Paths sCU_314 CD SRF Unit Boundary II 0 1.000 2 000 Soldotna Creek Unit Feet SCU 41B-04 Alaska State Plane Zane 4,HAD27 Hhlr,w1, %IA.L:.1.1.1 Map Date:10.,200014 Page 39 Revision 0 October, 2014 SCU 41B-04 in Drilling Procedure Rev 0 II ilrorp:11a4ka.1.1.1: 29.0 Surface Plat (As Built) (NAD 27) n % 2n, EECTIDN CORNER COMPUTED NORTH FROU CY,558 CMC 9:19 r Si} r 41111k+.�, 33 34 "',"'"jr . 4 3 •42•411.5412 9 E 7042-,....143 AS-BUIILT LOCATION WELL SCU 42-4 N:2480223.814 E_348506.271 ',%%NA%1x14 LAT'60'43'52634'N 9....',V.,4F 11 �\ i• $ LONG:150'51'27,0101N _�QZ S+/�� J \ - ASP ZONE 4 NA027 .07 'ry /I LL FEL.112T *; � .,. FNL=991' 49............._. . ..• ~ ELEV=173 7'(NAVD88I . . •••........ SECTION 4, •%':STAN A.MANE . — •—,._ T7N,REM,SM,AK /� 4s�7-S 1 �� `•\ \ III., ; ,*`�4 1/ FEL 1127' • r � / i 1 ( \ 1 1 \ 1 \ 1 - \ \ \ \ \ \ \ \ \ \ \ \ N, NOTES ` 1)BASIS OF COORDINATES:NGS-OPUS SOLUTION FROM CONS 'ZANE%*MON'AND?SEA'ALASKA STATE PLANE ZONE 414AD83 EPOCH 2003. 21BASIS OF ELEVATION:NGS BM 079 RESET 1991 NAV089. 3)SECTION LINE OFFSETS COMPUTED FROM 8LM CORNERS FOUND ALONG NORTH BOUNDARY OF 54 USED TO COMPUTE EAST BOUNDARY OF S4 SHOWN SCU 42-4 AS-BUILT SURFACE LOCATION / (NAD27) SWANSON RIVER FIELD till LOCATION:SECTION 4, TOWNSHIP 7 NORTH, ENGINEERING-TESTING4) RANGE 9 WEST,SEWARD MERIDIAN ALASKA SURVEYING-MAPPING P.O.BOX aseC. Ilik- p Alaska,1.11.4:SOLDOTNA,AK.99869 • JOB NO 133008 VOICE:(907}263.4218 FAX:(907)283.3265 DWG. Cawartbas lie WWW.MCLANECG,COM 133008 Date:2111/2013 FIGURE: 2 Page 40 Revision 0 October, 2014 SCU 41 B-04 H Drilling Procedure Rev 0 Itileorp Alaska,LL( 30.0 Surface Plat (As Built) (NAD 83) i SuF I SECTION CONNER CONFUTED NORTH FRDM CJ.558 MCMC 333.soy 33 34 a 3 j?"' N raana,s.a as AS-BUILT LOCATION WELL SCU 424 N:2459985 048 E:1488529.131 ......NZ‘1��:....-rvIIN.;141111,....... LAT:60'4350.606"N �.\ LONG:150'5134.998-W 'C,. •. q tor jASP ZONE4NAD83 `P. 4,f r FEL=1127' r* 9 f FNL=961 . `4,,9�� • ELEV.173.7'(NAVDBB} I X/ yAu., v N. •` SECTION 4, STAN A. MCLANE, " 17N,ROW,SM.AK •I�'►�, 4637-5 '+ .." SII�bp 2.f 04)--20,i # �, r FEL 1121' • r � 1 1 / / i ( 1 r \ r \ rr rr rr rr r \ rr r \ NOTES 1)OASIS OF COORDINATES:NGS OPUS SOLUTION FROM CORS ZANY,'TOON'AND?SEA'ALASKA STATE PLANE ZONE 4 NADB3 EPOCH 2003. Z1BASIS OF ELEVATION:NGS BM 079 RESET 1991 NAVDB8. 3'I SECTION LINE OFFSETS COMPUTED FROM BUN CORNERS FOUND ALONG NORTH BOUNDARY OF S4 USED TO COMPUTE EAST BOUNDARY OF S4 SHOWN ` } SCU 42-4 AS-BUILT SURFACE LOCATION (NAD83) SWANSON RIVER FIELD II LOCATION:SECTION 4, TOWNSHIP 7 NORTH, /7: ENGINEERING-TESTING SURVEYING-MAPPING RANGE 9 WEST,SEWARD MERIDIAN ALASKA P.O.80X488 Iti}rnrp Ala-ka,I.I.I. [ SOQ-OOTNA,AK.99869 JOB NO. 133008 voiCE:(907}2834218 FAX:1907)263.3265 DWG CwlsultInpMC WWW.MICLANEOO.CoM 133008 Date:2/1112013 FIGURE: 1 Page 41 Revision 0 October, 2014 x lo Hilcorp Energy Company Soldotna CK Unit '1 A Soldotna CK Unit Soldotna CK Unit 341-04 Plan: SCU 41B-04 Plan: SCU 41B-04 WP1.0 Standard Proposal Report i 17 September, 2014 a I Ii I ! ! as 5 s ' J-": ,,, HALLIBURTON -11 Er Air Sperry Drilling Services 4 1/2" N.- DETAILS: Soldotna CK Unit 341-04 \ .hound Level: 173.70 +N/-S +E/-W Northu.a Easting Latitude Longitude Slot \ 0.00 0.00 2460223.81 346506.27 60.7312872 -150.8575028 SCU 41 B-04 SR_H1 ST tgt ; , r 500 Project: Soldotna CK Unit Site: Soldotna CK Unit inSCU 41B-04 SR H7ST tgt SCU 41B-04 WP1.0 Well: Soldotna CK Unit 341-04 o — Wellbore: Plan: SCU 41B-04 Plan: SCU 41B-04 WP1.0 fV + I-. o 250 z 7" TOW HALLIBURTON Sperry Drilling Services 0 SCU 341-04.._ _\\' SCU 41A-04 _____ 1 __ SCU 42-04 -250 0 250 500 West(-)/East(+) (250 usft/in) 8500— KOP:Start Dir 12°/100':8605'MD,8604.51'TVD:60°LT TF _ 7"TOW -End Dir :8625'MD,8624.5'TVD 8750— Start Dir 5°/100':8655'MD,8654.47'TVD ---SR_TYNK_HP_H20 End Dir :9221'MD,9195.51'TVD 9000— - ----BSE HP-H20 KRE GRID - - 9250- - Start Dir 4.5°/100':9791.24'MD,9693.83'TVD 9500— 9 _ _ cn - n o 9750— LO - a - SCU 41 B-04 SR H1 ST tgt (1) 010000— , "iii10000— (8 C - SCU 42-04 1= End Dir : 10401.92'MD, 10277.1'TVD a) 10250—__-SR_H HIST -' _ (z� SCU 418-04 SR_H7ST tgt - SR_H5ST T M Azimuths to True North 10500— Magnetic North:16.97° ---SR_H7ST — Magnetic Field Strength:55499.3snT ----SR_H10ST- - - Dip Angle:73.72° 10750— 4 1/2" Date:9/17/2014 ' SCU 41A-04 Model:BGGM2013 - �� EOIO Total Depth: 11000'MD, 10874.94'TVD 11000— ( Y 1 REFERENCE INFORMATION - Co-ordinate(N/E)Reference: Well Soldotna CK Unit 341-04,True North - Vertical(TVD)Reference: SCU 41B-04 @ 192.00usft - ( l� Measured Depth Reference: SCU 41B-04 @ 192.00usft 11250— SCU 341-04_ Calculation Method: Minimum Curvature - i I I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Ii ! -1500 -1250 -1000 -750 -500 -250 0 250 500 750 1000 1250 1500 1750 2000 Vertical Section at 9.23° (500 usft/in) • - o o - ti - o a W C __O v.o Z WoS16 O WO - y r - .k00 q - 9 c r - o foo 0�n DwN2 _ ',,c.'.?-'= Q "EXi z 0C�(Oz - 10000 74 y m n ~Q S g o U 2 -056E —o 2 vivo y 0 =»- - LL 15 0 0 (%1 9 �N _ (A(n - w ad 6 a Ewh :E.,' - o '�' W r.,) a W¢ Ct¢�o - a .- a wU en- .= W j Halliburton H LLIBURTO■ . Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Soldotna CK Unit 341-04 Company: Hilcorp Energy Company TVD Reference: SCU 41B-04 @ 192.00usft - Project: Soldotna CK Unit MD Reference: SCU 41B-04 @ 192.00usft Site: Soldotna CK Unit North Reference: True Well: Soldotna CK Unit 341-04 Survey Calculation Method: Minimum Curvature Wellbore: Plan:SCU 41B-04 Design: SCU 41 B-04 WP1.0 Project Soldotna CK Unit,Swanson River Field Map System: US State Plane 1927(Exact solution) . System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) - Using Well Reference Point Map Zone: Alaska Zone 04 • Site Soldotna CK Unit Site Position: Northing: 2,460,278.17 usft Latitude: 60.7313645 From: Map Easting: 344,519.07 usft Longitude: -150.8686069 Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -0.76 ° Well Soldotna CK Unit 341-04 Well Position +N/-S 0.00 usft Northing: 2,460,223.81 usf• Latitude: 60.7312872 +E/-W 0.00 usft Easting: 346,506.27 usf . Longitude: -150.8575028 Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usf Ground Level: • 173.70 usft Wellbore Plan:SCU 41B-04 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2013 9/17/2014 16.97 73.72 55,499 Design SCU 41B-04 WP1.0 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,605.00 Vertical Section: Depth From(TVD) +N/-5 +E/-W Direction (usft) (usft) (usft) (°) 18.30 0.00 0.00 9.23 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (usft) (°) (°) (usft) usft (usft) (usft) (°/100usft) (°/100usft) (°/100usft) (°) 8,605.00 0.45 128.90 8,604.51 8,412.51 -10.78 7.35 0.00 0.00 0.00 0.00 8,625.00 2.65 77.34 8,624.50 8,432.50 -10.73 7.86 12.00 11.02 -257.80 -60.00 8,655.00 2.65 77.34 8,654.47 8,462.47 -10.42 9.22 0.00 0.00 0.00 0.00 9,221.00 29.09 6.93 9,195.51 9,003.51 131.93 39.23 5.00 4.67 -12.44 -75.04 9,791.24 29.09 6.93 9,693.83 9,501.83 407.14 72.70 0.00 0.00 0.00 0.00 10,401.92 1.61 8.37 10,277.10 10,085.10 566.04 92.25 4.50 -4.50 0.23 179.91 10,694.14 1.61 8.37 10,569.20 10,377.20 574.15 93.44 0.00 0.00 0.00 0.00 ' 11,000.00 1.61 8.37 10,874.94 10,682.94 582.65 94.69 0.00 0.00 0.00 0.00 9/17/2014 1:32:06PM Page 2 COMPASS 5000.1 Build 70 Halliburton HHALLIBURTO14IP Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Soldotna CK Unit 341-04 Company: Hilcorp Energy Company TVD Reference: SCU 41 B-04 @ 192.00usft Project: Soldotna CK Unit MD Reference: SCU 41B-04 @ 192.00usft Site: Soldotna CK Unit North Reference: True Well: Soldotna CK Unit 341-04 Survey Calculation Method: Minimum Curvature Wellbore: Plan:SCU 41B-04 Design: SCU 416-04 WP1.0 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) 8,412.51 8,605.00 . 0.45 128.90 8,604.51 8,412.51 -10.78 7.35 2,460,212.94 346,513.48 0.03 -9.46 KOP:Start Dir 12°/100':8605'MD,8604.51'TVD:60°LT TF 8,605.10 0.45 128.90 8,604.61 8,412.61 -10.78 7.35 2,460,212.94 346,513.48 0.00 -9.46 7"TOW 8,625.00 2.65 77.34 8,624.50 8,432.50 -10.73 7.86 2,460,212.99 346,513.99 12.06 -9.33 End Dir :8625'MD,8624.5'TVD 8,655.00 2.65 77.34 8,654.47 8,462.47 -10.42 9.22 2,460,213.27 346,515.35 0.00 -8.81 Start Dir 5°/100':8655'MD,8654.47'TVD 8,700.00 3.90 43.41 8,699.40 8,507.40 -9.08 11.29 2,460,214.59 346,517.44 5.00 -7.15 8,800.00 8.34 20.11 8,798.82 8,606.82 0.20 16.12 2,460,223.80 346,522.39 5.00 2.78 8,900.00 13.18 13.34 8,897.03 8,705.03 18.11 21.24 2,460,241.65 346,527.75 5.00 21.29 8,926.48 14.48 12.30 8,922.74 8,730.74 24.29 22.65 2,460,247.80 346,529.23 5.00 27.61 SR_TYNK_HP_H20 9,000.00 18.11 10.19 8,993.30 8,801.30 44.53 26.63 2,460,267.99 346,533.48 5.00 48.22 9,100.00 23.07 8.35 9,086.88 8,894.88 79.23 32.22 2,460,302.62 346,539.53 5.00 83.38 9,159.61 26.03 7.58 9,141.10 8,949.10 103.76 35.65 2,460,327.10 346,543.27 5.00 108.14 BSE_HP-H20_KRE_GRID 9,200.00 28.04 7.14 9,177.07 8,985.07 121.97 38.00 2,460,345.28 346,545.86 5.00 126.49 9,221.00 29.09 6.93 9,195.51 9,003.51 131.94 39.23 2,460,355.23 346,547.22 5.00 136.52 End Dir :9221'MD,9195.51'TVD 9,300.00 29.09 6.93 9,264.55 9,072.55 170.06 43.86 2,460,393.29 346,552.35 0.00 174.90 9,400.00 29.09 6.93 9,351.93 9,159.93 218.32 49.73 2,460,441.47 346,558.85 0.00 223.47 9,500.00 29.09 6.93 9,439.32 9,247.32 266.58 55.60 2,460,489.65 346,565.35 0.00 272.05 9,600.00 29.09 6.93 9,526.71 9,334.71 314.84 61.47 2,460,537.83 346,571.85 0.00 320.63 9,700.00 29.09 6.93 9,614.09 9,422.09 363.11 67.34 2,460,586.01 346,578.35 0.00 369.21 9,791.24 29.09 6.93 9,693.83 9,501.83 407.14 72.70 2,460,629.97 346,584.28 0.00 413.53 Start Dir 4.5°/100':9791.24'MD,9693.83'TVD 9,800.00 28.69 6.94 9,701.50 9,509.50 411.34 73.21 2,460,634.16 346,584.85 4.50 417.76 9,900.00 24.19 6.95 9,791.01 9,599.01 455.54 78.59 2,460,678.28 346,590.80 4.50 462.24 10,000.00 19.69 6.98 9,883.74 9,691.74 492.62 83.12 2,460,715.31 346,595.82 4.50 499.58 10,100.00 15.19 7.01 9,979.12 9,787.12 522.37 86.77 2,460,745.01 346,599.86 4.50 529.52 10,200.00 10.69 7.08 10,076.55 9,884.55 544.60 89.52 2,460,767.20 346,602.89 4.50 551.90 10,300.00 6.19 7.25 10,175.44 9,983.44 559.16 91.34 2,460,781.74 346,604.91 4.50 566.58 10,400.00 1.70 8.29 10,275.18 10,083.18 565.98 92.24 2,460,788.55 346,605.89 4.50 573.45 10,401.92 1.61 8.37 10,277.10 10,085.10 566.04 92.25 2,460,788.60 346,605.90 4.50 573.51 End Dir :10401.92'MD,10277.1'TVD 10,401.93 1.61 8.37 10,277.11 10,085.11 566.04 92.25 2,460,788.60 346,605.90 1.11 573.51 SR_H1ST 10,500.00 1.61 8.37 10,375.14 10,183.14 568.76 92.65 2,460,791.32 346,606.34 0.00 576.26 10,587.91 1.61 8.37 10,463.01 10,271.01 571.20 93.01 2,460,793.76 346,606.73 0.00 578.73 SR H5ST 10,600.00 1.61 8.37 10,475.10 10,283.10 571.54 93.06 2,460,794.09 346,606.78 0.00 579.07 10,694.14 1.61 8.37 10,569.20 10,377.20 574.15 93.44 2,460,796.70 346,607.20 0.00 581.71 10,694.17 1.61 8.37 10,569.23 10,377.23 574.16 93.44 2,460,796.70 346,607.20 0.00 581.71 SR_H7ST 9/17/2014 1:32:06PM Page 3 COMPASS 5000.1 Build 70 Halliburton HALLIBURTOi .. Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Soldotna CK Unit 341-04 Company: Hilcorp Energy Company TVD Reference: SCU 41B-04 @ 192.00usft Project: Soldotna CK Unit MD Reference: SCU 41B-04 @ 192.00usft Site: Soldotna CK Unit North Reference: True Well: Soldotna CK Unit 341-04 Survey Calculation Method: Minimum Curvature Wellbore: Plan:SCU 41B-04 Design: SCU 41B-04 WP1.0 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) 10,383.06 10,700.00 1.61 8.37 10,575.06 10,383.06 574.32 93.46 2,460,796.86 346,607.23 0.00 581.87 10,800.00 1.61 8.37 10,675.02 10,483.02 577.10 93.87 2,460,799.63 346,607.67 0.00 584.68 10,825.05 1.61 8.37 10,700.06 10,508.06 577.79 93.98 2,460,800.33 346,607.78 0.00 585.38 SR_H10ST 10,900.00 1.61 8.37 10,774.98 10,582.98 579.87 94.28 2,460,802.41 346,608.12 0.00 587.49 10,999.99 1.61 8.37 10,874.93 10,682.93 582.65 94.69 2,460,805.18 346,608.56 0.00 590.29 Total Depth:11000'MD,10874.94'TVD-4 1/2" -11,000.00 1.61 8.37 10,874.94 ,10,682.94 582.65 94.69 2,460,805.18 346,608.56 0.00 590.29 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +NI-S +E/-W Northing Easting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) SCU 41B-04 SR_H7ST tot 0.00 0.00 10,569.20 574.15 93.44 2,460,796.70 346,607.20 -plan hits target center -Circle(radius 100.00) SCU 41B-04 SR_H1 ST tgt 0.00 0.00 10,277.10 566.04 92.25 2,460,788.60 346,605.90 -plan hits target center -Circle(radius 100.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 8,605.10 8,604.61 7"TOW 7 8-1/2 10,999.99 10,874.93 41/2" 4-1/2 6-1/8 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (usft) (usft) Name Lithology (1 (°) 8,926.48 8,922.74 SR_TYNK_HP_H20 9,159.61 9,141.10 BSE_H P-H20 10,825.05 10,700.06 SR_H1 OST 10,401.93 10,277.11 SR_HIST 10,694.17 10,569.23 SR_H7ST 10,587.91 10,463.01 SR_H5ST 9/17/2014 1:32:06PM Page 4 COMPASS 5000.1 Build 70 / Halliburton L � T Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Soldotna CK Unit 341-04 Company: Hilcorp Energy Company TVD Reference: SCU 41B-04 @ 192.00usft Project: Soldotna CK Unit MD Reference: SCU 41B-04 @ 192.00usft Site: Soldotna CK Unit North Reference: True Well: Soldotna CK Unit 341-04 Survey Calculation Method: Minimum Curvature Wellbore: Plan:SCU 41B-04 Design: SCU 41B-04 WP1.0 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 8,605.00 8,604.51 -10.78 7.35 KOP:Start Dir 12°/100':8605'MD,8604.51'TVD:60°LT TF 8,625.00 8,624.50 -10.73 7.86 End Dir :8625'MD,8624.5'TVD 8,655.00 8,654.47 -10.42 9.22 Start Dir 5°/100':8655'MD,8654.47'TVD 9,221.00 9,195.51 131.94 39.23 End Dir :9221'MD,9195.51'TVD 9,791.24 9,693.83 407.14 72.70 Start Dir 4.5°/100':9791.24'MD,9693.83'TVD 10,401.92 10,277.10 566.04 92.25 End Dir : 10401.92'MD, 10277.1'TVD 10,999.99 10,874.93 582.65 94.69 Total Depth : 11000'MD, 10874.94'TVD 9/17/2014 1:32:06PM Page 5 COMPASS 5000.1 Build 70 Zto 0 m 0 5 .c, cc n 3 c CO Q J I L QmL Z a C3. 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N O N 0 0. /� Q — Ei aD O n O N OCO I m (u!/o9'Z) _loped uol1eaedag Q U Davies, Stephen F (DOA) From: Monty Myers <mmyers@hilcorp.com> Sent: Wednesday, October 29, 2014 3:31 PM To: Davies, Stephen F(DOA) Subject: RE: SCU 41B-04 (PTD#214-177) Logging Program I mention gathering LWD data on page 7 section 7 of the drilling procedure, however it does not specifically call out what logging tools will be run. Since this is a 6" hole size we may want to limit the tools to GR/RES only.Also, Luke is prepping to evaluate the Falls Creek 6 well with thru bit logging technology, and that may be what I would prefer to try on the SCU 41B-04 if he is successful with it down there. That would consist of the full triple combo. If he is successful and we want to use it,then we will drill with a slick assembly with GR/RES, the I will have the rig make a dedicated cleanout run with the thru bit tools. Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Wednesday, October 29, 2014 2:45 PM To: Monty Myers Subject: RE: SCU 41B-04 (PTD #214-177) Logging Program Monty, In the SCU 41B-04 Permit to Drill application, I don't see LWD tools in the list of component parts for the BHA, and LWD acquisition isn't specifically mentioned in the proposed drilling program. Questions: 1. Does Hilcorp plan to record LWD measurements from the whipstock to the TD of the SCU 41B-04 well? 2. If not,what downhole logs are planned? 3. How will the logging program be communicated to the rig crew? 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: Monty Myers [mailto:mmyers@hilcorp.com] Sent: Monday, October 27, 2014 8:58 AM To: Davies, Stephen F (DOA) Subject: FW: SRU 21C-04 (PTD #214-169) 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: �� ceeL 4;_( PTD: / 7 7 Development Service Exploratory Stratigraphic Test Non-Conventional IC__ POOL: 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 are / also required for this well: lie ' e" L�'' c� I Well Logging /`e? ,�GZI�L/�t2��. � -6 ' i- eASitc_s4- / " ,Requirements A -f- Per tatut31.05.03Qjd4 L (B) and Regulatiah 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 C-"ei . well. Revised 4/2014 El (0 0) o , , . . . . . . . . . . . . . . . . . . . . . . . . N 0 , , , , , , , , � , , , , � , � , , , , � , , , LI, Z. ur c o. o c � Y. 3. o �. C 3 a) a . . . . . 4 gyp, N, N, O . . L. `g, y p . . . . . . , . . . . . . a . y. a. w C, E O , co. , ami, 3' '' c y. . . , . . . . . . . . . . in . �. c) o a;. m 0. a`i c, o. €, €, , , , , 0) EL , o , , , , , , , , , , , Nc3. c o • w pas cw . L, . �. O . a LL, rn o. p. ' oo �. =. o - O as a _ c N. 3. v. L. m . . ,�. v. 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To improve the readability of the Well History file and to simpI fy 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. Technical Report Title Date Client: Hilcorp Alaska, LLC Field: Swanson River Field Rig: Saxon 169 Date: January 26, 2015 Surface Data Logging End of Well Report SCU 41B-04 TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Days vs. Depth 4. After Action Review 5. Mud Record 6. Bit Record 7. Morning Reports 8. Survey Report Digital Data to include: Final Log Files Final End of Well Report Final LAS Exports Halliburton Log Viewer EMF Log Viewer GENERAL WELL INFORMATION Company: Hilcorp Alaska, LLC Rig: Saxon 169 Well: Soldotna Creek Unit 41B-04 Field: Swanson River Field Borough: Kenai Peninsula Borough State: Alaska Country: United States API Number: 50-133-10109-03-00 Sperry Job Number: AK-XX-0901916736 Job Start Date: 19 December 2014 Spud Date: 8 April 2014 Total Depth: 11003’ MD, 10829’ TVD North Reference: True Declination: 16.92° Dip Angle: 73.72° Total Field Strength: 55472 nT Date of Magnetic Data: 15 December 2014 Wellhead Coordinates N: North 60° 43’ 52.634” Wellhead Coordinates W: West 150° 51’ 27.010” Drill Floor Elevation 191.70’ Ground Elevation: 173.70’ Permanent Datum: Mean Sea Level SDL Engineers: Jeremy Tiegs, Jane Grundin SDL Sample Catchers: Ryan Lenberg, Lesley Hunter Company Geologist: John Serbeck, Kevin Eastham Company Representatives: Rance Pederson, Joe Grubb, Doug Yessak, Shane Barber Sperry Mudlogging Unit Number: 117 Monitoring Gas Equipment Summary: Baseline 9000 Gas Analyzer Baseline 8900 Gas Chromatograph Matheson Chrysalis Hydrogen Generator Critical Spare Gas Equipment Summary: Baseline 9000 Gas Analyzer Baseline 8900 Gas Chromatograph Matheson Chrysalis Hydrogen Generator HOLE DATA Dates Drilled Hole Section Total Depth Mud Weight (ppg) Inclination (degrees) Casing Shoe Depth MD TVD MD TVD 12/23/14 – 01/03/15 6” 11,000’ 10,828’ 9.5-11 17 - - - 01/17/2015- 01/23/2015 6” 11,003’ 10,829’ 9.5-11 17 4.2” 10,998 10,822 DAILY SUMMARY 12/19/2014 SDL arrived on location and began rigging up unit and equipment. Connected communication cables and Pason data transfer system. 12/20/2014 Ran in hole to 9,379' MD and circulated, well taking about 21 bph. Tripped out of hole with scraper BHA for Retrievable Test Treat Squeeze (RTTS) packer. Make up RTTS packer assembly and ran in hole with 2 7/8" tubing to 937' MD. Ran in hole with 4 1/2" drill pipe to 9,495' MD and tested RTTS packer. Pressured up front side and lost pressure. Pressured up back side and pressure held. Tripped in hole above cast iron bridge plug at 10,278' MD where pressure was lost on the front side but held on the back side. Tripped out of hole at time of report for new cast iron bridge plug. Gas: No formation gas. Fluids: 294 barrels of produced water lost downhole. 12/21/2014 Ran in hole with cement bails and dumped them on the cast iron bridge plug. Capped the bails with mud. Rigged down Wireline, well taking ~20 bph produced water. Made up scraper assembly, picked up singles and running in hole at time of report. Gas: No formation gas. Fluids: 355 barrels of produced water lost downhole. 12/22/2014 Tripped out of hole and racked back drill pipe, laid down 2 7/8" tubing. Rigged up wire line and ran in hole with cast iron bridge plug. Set cast iron bridge plug @ 10,297' MD and attempted to test to 2600 psi, tested to 2300 psi. Ran in hole with second cast iron bridge plug to 10,275' MD. Tested casing to 2600 psi for 30 min, passed. Rigged up wireline cement bails and dumped 35' cement. Picked up cast iron bridge plug and running in hole at time of report. Gas: No formation gas. Fluids: 155 barrels of produced water lost downhole. 12/23/2014 Running in hole to 9,086' MD and set the cast iron bridge plug; lay down Wireline. Changed out bottom pipe rams and tested rams. Rigged up milling assembly and picked up whipstock. Send in hole to 793' MD and ran in hole with stand from derrick. Rigged up wireline and ran in hole. Oriented whipstock and preparing to set at time of report. Gas: No formation gas. Fluids: 0 barrels of mud gained or lost downhole. 12/24/2014 Sheared and set whip-stock. Displaced well from produced water to WBM 9.8 ppg mud. Began milling window at 9,055'MD and exited window at 9,068'MD. Drilled ahead to 9089’ MD into formation, conducted flow check and well was static. Pumped a high viscosity sweep and had a 10% increase in cuttings at shakers at bottoms up. Collected total of 118 lbs metal shavings. Performed FIT to estimated mud weight of 12.5 ppg (1278 psi). Pumped dry job and TOOH to surface and well remained static. Servicing rig and prepping to pick up new BHA. Gas: 6 units of trip gas, no formation gas. Fluids: 0 barrels of mud gained or lost downhole. 12/25/2014 Uploaded MWD data, tripped in hole to 5,375' MD. Tripped in hole on singles from 5,375' MD to 6,440' MD. Tripped in hole with stands from derrick to window, slip and cut drill line. Pick up side entry sub and rig up wireline. Began drilling with gyro, drilling ahead at time of report. Gas: 1,937 units of trip gas, no formation gas. Fluids: 0 barrels of mud gained or lost downhole. 12/26/2014 Continued drilling with gyro until communications with tool lost. Rigged down wireline and waited on new truck. Rigged up wireline and ran in hole. Circulated bottoms up 440 units. Drilled ahead from 9,092' MD to 9102' MD. Pumped sweep and drilled ahead to 9,109'MD. Begin tripping out of hole for new bit. Rigged down wireline, pump sweep, pump slug, tripping out of hole at time of report. Gas: 77 units of trip gas, no formation gas, no connection gas. Fluids: 0 barrels of mud gained or lost downhole. 12/27/2014 Tripped out of hole to surface. Swapped motor and bit and ran in hole to 9,089’ MD. Circulated bottoms up 536 units. Rigged up and ran in hole wireline. Began drilling at time of report. Gas: 536 units of trip gas, 3 units of formation gas, no connection gas. Fluids: 0 barrels of mud gained or lost downhole. 12/28/2014 Continued drilling with gyro from 9,109' MD to 9,115' MD. Pumped sweep. Picked up to 9,094' MD and rigged up wireline. Drilled ahead from 9,115' MD to 9,128' MD. Rigged up wireline and continued sliding. Pumped sweep. Continued drilling to 9,151' MD and rigged up wireline. Pulled out of hole with wireline at the time of report. Gas: 187 units formation gas, no trip gas, no connection gas. Fluids: 0 barrels of mud gained or lost downhole. Geology: 100% Sandstone: light grey, firm, homogenous, Quartz sandstone with translucent to clear, fine to medium, sub-rounded, moderately sorted, poorly cemented grains, tuffaceous, trace Coal; No stain, odor, fluorescence, or cut. 12/29/2014 Finished rigging up wireline. Drilled ahead, rotating from 9,151' MD to 9,161' MD. Rigged up wireline and ran in hole. Drilled ahead to 9,166' MD. Rigged down wireline and drilled ahead to 9,460' MD at time of report. Gas: 254 units formation gas, no trip gas, 402 connection gas. Fluids: 0 barrels of mud gained or lost downhole. Geology: 100% Sand: translucent to transparent, gray quartz with fine to course gr with occasional very coarse quartz grains, sub-rounded, sub-spherical, poorly sorted, tuffaceous with occasion hard sandstone with rare pyrite. No stain, odor, fluorescence, or cut. 12/30/2014 Continued drilling ahead from 9,466' MD to 9,715' MD, checked flow- 14 bph. After seeing 9,534 units connection gas, weighted up to 10.0 ppg mud weight. Drilled to 9,779' MD, checked flow- 10 bph, and saw 1,965 units of connection gas. Weighted up to 10.2 ppg mud weight. Drilled to 9,840' MD, checked flow- 10 bph, saw 6,679 units connection gas. Weighted up to 10.4 ppg mud weight. Drilled to 9,899' MD, checked flow- 20 bph, saw 7,083 units connection gas. Weighted up to 10.6 ppg mud weight. Saw 7,467 units connection gas at 9,976' MD. Drilled to 10,082’ MD, flowing at 16 bph, drilling ahead at time of report. Gas: Maximum formation gas seen was 180 units at 9,800’ MD, maximum connection gas was 9,534 units, and there was no trip gas. Fluids: 0 barrels of mud gained or lost downhole. Geology: 100% Siltstone: medium-light grey, firm, homogenous, slightly tuffaceous, well compacted, non-calcareous; No stain, odor, fluorescence, cut. 12/31/2014 Drilled ahead from 10,082' MD to 10,274' MD seeing max connection gas of 7,166 units and flow of 9 barrels per hour. Pumped sweep, weighted up mud to 10.8 ppg, and pulled back to 9,888' MD. Checked flow- 10 barrels per hour, ran back to bottom, circulated bottoms up 7,954 units of gas, and weighted up mud to 11.0 ppg. Checked flow- 6 barrels per hour, began tripping out of hole. Checked flow at window- 5.2 barrels per hour, pumped 13 ppg pill. Tripped out of hole to 3,452' MD and pumped another 13 ppg pill. Checked flow- 5.3 barrels per hour, continuing to trip out of hole for BOP test at time of report. Gas: Maximum formation gas seen was 113 units at 10,256’ MD, maximum connection gas was 7,166 units, and maximum trip gas was 7,954 units. Fluids: 0 barrels of mud gained or lost downhole. Geology: 60% Siltstone: light-dark grey, trace brown/black, moderately firm, homogenous, non- calcareous; No stain, odor, fluorescence, cut; 40% Sand: clear-opaque, Quartz, very fine-fine grain, sub round, spherical, moderately sorted. 01/01/2015 Finished tripping out of hole, 10 barrels per hour of flow. Run in hole with mud motor and bit to 59'MD to isolate during BOP test. Completed BOP test. Rig up to pull packer out. Opened up with 11 barrels per hour of flow, laying down packer at time of report. Gas: Maximum trip gas observed was 6 units, there was no formation or connection gas. 01/02/2015 Lay down packer and run in hole to 1,630' MD. Circulated bottoms up 1,874 units of gas, run in hole to 2,747' MD, circulated bottoms up 8,890 units of gas. Run in hole to 4,388' MD, circulated bottoms up 9,577 units of gas and dumped 100 barrels of diluted mud and water. Run in hole to 6,000' MD, circulated bottoms up 8,523 units of gas, dumped another 88 barrels of mud and water. Run in hole to 9,025' MD and circulated bottoms up 6,740 units of gas, dumped another 164 barrels. Run in hole to 9,127' MD and began washing and reaming. Got back on bottom and drilling ahead at time of report. Gas: 116 was maximum formation gas seen at 10,285’ MD, maximum trip gas seen was 9,581 units, and there was no connection gas. Fluids: 0 barrels of mud gained or lost downhole. Geology: Geology: 40% Siltstone: dark brown, soft, earthy, non-calcareous; light grey, firm, homogenous, tuffaceous, non-calcareous; No stain, odor, fluorescence, cut; 30% Coal: very dark brown, hard, splintery; 20% Shale; 10% Sandstone. 01/03/2015 Drilled ahead from 10,290' MD to 10,337' MD and checked flow- 8.5 barrels per hour. Drilled to 11,000' MD and pumped sweep. Called total depth. Checked flow, 6.4 barrels per hour. Trip out of hole to shoe as wiper trip at time of report. Gas: 314 units was maximum formation gas seen at 10,640’ MD, maximum trip gas seen was 48 units, and maximum connection gas was 667 units. Fluids: 0 barrels of mud gained or lost downhole. Geology: 90% Sand: clear-translucent, Quartz, very fine-medium grain, moderately sorted, sub round, subspherical, tuffaceous, silty; No stain, odor, fluorescence, cut; 10% Sandstone. 01/04/2015 Run in hole to bottom, pumped sweep. Dumped 35 bbls of water/mud and spotted a pill on bottom. Tripped out of hole to 9,011' MD and spotted another pill. Tripped out of hole to 5,283' MD and pumped dry job. Checked flow- 2.8 barrels per hour. Tripped out of hole leaving the bottom hole assembly in the hole, checked flow- 7.1 barrels per hour. Lay down bottom hole assembly and picked up Madpass tools at time of report. Gas: No formation gas, observed 45 units maximum trip gas. Fluids: 0 barrels of mud gained or lost downhole. Geology: Sample collection has concluded. 01/05/2015 Run in hole with MWD tools to 4,066' MD and checked flow- 5 barrels per hour. Run in hole to 7,165' MD, checked flow- 9.8 barrels per hour. Run in hole to 9,034' MD, circulated bottoms up 9,880 units of gas, dumped 143 bbls of water/mud. Couldn't get through window, spotted a pill at 9,035' MD. Dropped rabbit on wire down drill pipe, and tripped out of hole to inspect bottom hole assembly. Checked flow at 5,876' MD- 1.5 barrels per hour. Lay down the bottom hole assembly at time of report. Gas: No formation gas, 9,880 units of trip gas seen. Fluids: 0 barrels of mud gained or lost downhole. 01/06/2015 Lay down bottom hole assembly, checked flow- 9.2 barrels per hour. Plan to re-mill window, pick up milling assembly and began running in hole. Circulated surface-to-surface 9,882 units of gas at 4,901' MD and dumped 33 bbls water/mud. Checked flow- 18 barrels per hour and continued running in hole to 6,067' MD. Dumped 88 bbls water/mud and run in hole to 6,601' MD. Checked flow- 11.8 barrels per hour, run in hole to 9,020' MD, dumped 134 bbls water/mud, and run in hole to window. Began milling window and cleaning it up at time of report. Gas: No formation gas, 9,882 units of trip gas seen. Fluids: 0 barrels of mud gained or lost downhole. 01/07/2015 Finished re-milling the window and checked flow- 2.6 barrels per hour. Pull out of hole to 9,023' MD, circulated and slip and cut drill line. Spotted pill and checked flow- 1.8 barrels per hour. Tripped out of hole to 4,350' MD, checked flow- 2.2 barrels per hour, and finished tripping out of hole. Lay down bottom hole assembly, checked flow- 4.2 barrels per hour, and picked up clean out assembly. Run in hole to 964' MD and checked flow- 5.8 barrels per hour. Run in hole to 9,037' MD and circulated, dumping 57 bbls of water/mud. Run in hole to 9,075' MD and began washing/reaming. Continuing to wash down at time of report. Gas: No formation gas, 9,876 units of trip gas seen. Fluids: 0 barrels of mud gained or lost downhole. 01/08/2015 Washed and reamed to bottom seeing max gas of 8,708 units. Checked flow at 10,466' MD- 11.8 barrels per hour. Pumped sweep and circulated bottoms up 9,065 units of gas. Checked flow- 9.3 barrels per hour. Conducted 1000' wiper trip and ran back to bottom, pumped sweep, and began weighting up mud from 10.6 ppg to 10.8 ppg. Tripped out of hole to window and checked flow- 0.6 barrels per hour. Spotted 13 ppg mud cap and checked flow- 0.8 barrels per hour. Tripped out of hole to surface, lay down bottom hole assembly, and rig up to run 4.5" production liner at time of report. Gas: No formation gas, 9,065 units of trip gas seen. Fluids: 0 barrels of mud gained or lost downhole. 01/09/2015 Finished rigging up liner, made up shoe track, and checked flow- 5.5 barrels per hour. Run in hole with 4.5" production liner to 9,048' MD and circulated bottoms up. Saw max gas of 9,152 units, dumped 77 bbl water/mud. Could not make it through window, decided we would pull out of hole. Circulated bottoms up 4,601 units of gas, spotted 13.5 ppg mud cap, and checked flow- static. Began pulling out of hole to surface, made up new liner running tool, and preparing to run in hole at time of report. Gas: No formation gas, 9,151 units of trip gas seen. Fluids: 0 barrels of mud gained or lost downhole. 01/10/2015 Run in hole with new liner running tool to 2,371' MD, checked flow- 5 barrels per hour. Run in hole to 6,790' MD, circulating bottoms up 9,625 units of gas and dumped 35 bbls water/mud. Attached fish and pull out of hole with fish, checked flow- 0.5 barrels per hour. Pull out of hole to surface, lay down liner, and checked flow- 9.7 barrels per hour. Made up milling bottom hole assembly, and begin running in hole to 2,183' MD. Circulated bottoms up 5,812 units of gas. Run in hole to 3,739' MD and circulate bottoms up 9,817 units of gas and dumped 38 bbls water/mud. Continuing to run in hole at 4,977' MD at time of report. Gas: No formation gas, 9,817 units of trip gas seen. Fluids: 0 barrels of mud gained or lost downhole. 01/11/2015 Run in hole to 5,282' MD, circulating bottoms up 9,880 units of gas and dumping 65 bbls of water. Run in hole to 6,851' MD, circulated bottoms up 7,222 units of gas and dumped 78 bbls of water. Run in hole to 9,021' MD, circulated bottoms up 9,172 units of gas and dumped 106 bbls of water. Re-dressed window per Baker rep- collected 54 bbl of metal shavings. Pumped sweep, pulled 1 stand and pumped 13 ppg mud cap. Slip and cut drill line, checked flow- 1.3 barrels per hour. Trip out of hole with milling assembly, checked flow- 2.6 barrels per hour. Making up cleanout bottom hole assembly at time of report. Gas: No formation gas, 9,880 units of trip gas seen. Fluids: 0 barrels of mud gained or lost downhole. 01/12/2015 Run in hole with cleanout bottom hole assembly to 9,006' MD. Circulated bottoms up 9,861 units of gas and dumped 41 bbls of water/mud. Run in hole to 9,068' MD and washed/reamed down to 9,079' MD. Took spot samples every ~10 minutes, saw <15% cement with Phenolphthalein. Attempted to rotate through open hole, could not. Decided to pull out of hole. Checked flow- 2 barrels per hour, pumped 13 ppg mud cap, and checked flow- 3 barrels per hour. Began pulling out of hole to surface, pulling out of hole at 1,517' MD at time of report. Gas: No formation gas, 9,861 units of trip gas seen. Fluids: 0 barrels of mud gained or lost downhole. 01/13/2015 Finished pulling out of hole to surface, service rig, and made up milling assembly. Run in hole to 9,002' MD, circulated bottoms up 9,861 units of gas and dumped 64 bbls water/mud. Run in hole to 9,075' MD and milled through junk to 9,082' MD. Pumped sweep, then another sweep, then decided to pull out of hole. Spotted 13 ppg mud cap, began pulling out of hole to surface. Checked flow- static. Pulling out of hole at 8,686' MD at time of report. Gas: No formation gas, 9,861 units of trip gas seen. Fluids: 0 barrels of mud gained or lost downhole. 01/14/2015 Finished pulling out of hole to surface. Lay down bottom hole assembly, performed rig service, and trip in hole with milling assembly and bent sub to 9,036' MD. Circulated bottoms up 9,872 units of gas and dumped 63 bbls water/mud. Washed/reamed to 9,079' MD, pumped sweep, and checked flow- 0.9 barrels per hour. Milled to 9,099' MD and pumped sweep. Milling ahead at 9,101' MD at time of report. Gas: No formation gas, 9,872 units of trip gas seen. Fluids: 0 barrels of mud gained or lost downhole. 01/15/2015 Continue milling from 9,101' MD to 9,177' MD, pumping sweeps at 9,113' MD, 9,122' MD, and 9,177' MD. Pull out of hole to top of window and checked flow- static. Pumped 13 ppg mud cap. Continued pulling out of hole to surface to test blow out preventer. Checked flow- 0.5 barrels per hour. Testing blow out preventer at time of report. Gas: No formation gas, 107 units of trip gas seen. Fluids: 0 barrels of mud gained or lost downhole. 01/16/2015 Completed and passed blow out preventer testing. Rig down test equipment and pulled test plug. Slip/cut drill line and serviced rig. Make up directional bottom hole assembly and test- MWD tools failed. Changed collars and retested- passed. Re-install wear bushing, and pick up heavy weight drill pipe. Begin running in hole, running in hole at 9,050' MD at time of report. Gas: No formation gas or trip gas was seen. Fluids: 0 barrels of mud gained or lost downhole. 01/17/2015 Rig up Wireline and run in hole to 9,050' MD, through window. Circulate bottoms up 5,690 units of gas. Pull out of hole with Wireline and lay down Gyro. Trip in hole from 9,050' MD to 9,127' MD, wash/ream to 9,177' MD. Pick up Gryo, run in hole with Wireline, take surveys from 9,120' MD to 9,070' MD. Pull out of hole with Wireline, lay down Gyro. Drilled to 9,207' MD and circulate bottoms up. Pick up Gyro and run in hole with Wireline, took surveys. Decided to drill ahead, drilling ahead with Gyro at 9,215' MD at time of report. Gas: Maximum formation gas seen was 27 units at 9,211’ MD, and maximum trip gas was 5690 units. Fluids: 0 barrels of mud gained or lost downhole. 01/18/2015 Drill ahead with Gyro from 9,215' MD to 9,230' MD. Serviced rig, and drill ahead from 9,230' MD to 9,242' MD. Pull out of hole with Wireline and Gyro for connection, then run in hole with Wireline and Gyro. Continue drilling ahead to 9,250' MD. Pull out of hole with Wireline and Gyro, rig down. Checked flow- 7 barrels per hour, circulated bottoms up 4,045 units of gas. Pumped sweep. Drilling ahead at 9,277' MD at time of report. Gas: Maximum formation gas seen was 4,045 units at 9,252’ MD, and there was no trip gas or connection gas seen. Fluids: 0 barrels of mud gained or lost downhole. Geology: 100% Siltstone: medium brown-grey, firm, blocky, homogenous, non-calcareous, slightly tuffaceous, rare Sandstone; No stain, odor, fluorescence, or cut. 01/19/2015 Continued drilling ahead from 9,277' MD to 9,294' MD, service rig. Drilled from 9,294' MD to 9,326' MD and rig down Wireline. Circulate bottoms up 5,742 units, check flow-9 barrels per hour, continued drilling ahead. Drilling ahead at 9,424' MD at time of report. Gas: Maximum formation gas seen was 140 units at 9,314’ MD, max connection gas was 397 units, max bottoms up was 5,742 units. Fluids: 0 barrels of mud gained or lost downhole. Geology: 100% Sandstone : white, soft, fine-coarse grain, rare very coarse clear quartz grain, sub- rounded, moderate-poorly sorted, poorly consolidated, Tuff cement, common Sand, trace Siltstone, rare Coal; No stain, odor, fluorescence, or cut. 01/20/2015 Drilling ahead at 9,424’ MD, check flow -12 barrels per hour, continued drilling to 9,445' MD. Pumped sweep and drilled to 9,581' MD and circulate bottoms up of 182 units of gas. Pulled out of hole to window, checked flow -10 barrels per hour, and spotted 13 ppg mud cap. Continued pulling out of hole to surface for new bottom hole assembly, complete pulling out of hole and laying down bottom hole assembly at time of report. Gas: Maximum formation gas seen was 126 units at 9,466’ MD, max connection gas was 364 units. Fluids: 0 barrels of mud gained or lost downhole. Geology: 50% Siltstone : light gray, soft-friable, amorphous, sandy, homogenous, non-calcareous, occasional light gray Sandstone, rare dark gray-tan Siltstone fragments; No stain, odor, fluorescence, or cut. : 40% Sand: light gray, localized brown, clear-translucent, Quartz, lithics, coarse-medium, sub- angular, moderate sorting, common Glauconite, common Coal; 10% Sandstone. 01/21/2015 Flow check - 8 barrels per hour and finished laying down bottom hole assembly. Made up new bottom hole assembly and began running in hole. Flow check - 8.5 barrels per hour, continued running in hole to 7021' MD, circulated bottoms up with 9,137 units of gas, and dumped 98 bbls of water/mud. Flow check - 20 barrels per hour, continued running in hole to 9,040' MD picked up Gyro and ran in hole on wire line, orientated tools, and exited window. Flow check - 22 barrels per hour, ran in hole to 9,276' MD, circulated bottoms up with 7,744U of gas and dumped 231 bbls of water/mud. Drilled ahead to 9,638' MD, flow check - 1.5 barrels per hour. Drilling ahead at 9,657' MD at time of report. Gas: Maximum formation gas seen was 59 units at 9,632’ MD, max connection gas was 65 units and maximum trip gas was 9,137 units. Fluids: 0 barrels of mud gained or lost downhole. Geology: 60% Sandstone: light grey-grey, white, soft, heterogeneous, Quartz grain, very fine grain, sub- rounded, poor-moderate sorted, common tuff cement, silty in places, rare Coal fragments; no stain, odor, fluorescence, or cut. 40% Siltstone: dark brown, black, rare tan, very hard, angular, occasional laminations, homogeneous. 01/22/2015 Continued drilling from 9,657' MD to 9,700' MD, checked flow- 1 barrel per hour. Drilled to 9,763' MD, checked flow- 3.5 barrels per hour. Pumped sweep and drilled ahead to 9,908' MD. Entered previous well bore and worked intersection, washed and reamed to 10,260' MD. Decided to pull out of hole to point of intersection to rework, checked flow- 8.5 barrels per hour. After reworking, tripped out of hole to 10,260' MD, washed and reamed to bottom, confirmed on bottom by Directional Driller. Pumped sweep, circulated bottoms up minimal gas and began pulling out of hole for Madpass. Pulling out of hole at 10,833' MD at time of report. Gas: Maximum formation gas seen was 9,941 units at 9,929’ MD, max connection gas was 7,979 units and maximum trip gas was 5,610 units. Fluids: 0 barrels of mud gained or lost downhole. Geology: 90% Sand: clear-translucent, white, light grey-grey, Quartz, lithic, sub-round, very fine-fine grain, well sorted; No stain, odor, fluorescence, cut; 10% Siltstone. 01/23/2015 Continued pulling out of hole from 10,833' MD to 10,627' MD. Checked flow- 2.5 barrels per hour. Pulling out of hole to 9,110' MD, run in hole to bottom, pumped sweep, spotted pill, and pull out of hole to 8,996' MD. Checked flow- 1.5 barrels per hour and spotted 13 ppg mud cap, pull out of hole to 3,250' MD. Began laying down singles and continued pulling out of hole to surface. Lay down bottom hole assembly and downloaded tools, laying down bottom hole assembly at time of report. Gas: There was no formation gas or connection gas, maximum trip gas was 9,575 units. Fluids: 0 barrels of mud gained or lost downhole. Geology: Sample collection has concluded. 01/224/2015 Finished laying down drill pipe and bottom hole assembly, checked flow- 4.3 barrels per hour. Rig up Weatherford and began running in hole with 4.5" liner. Pick up liner hanger and switch to drill pipe. Run in hole to 8,990' MD and circulated surface to surface with max gas of 9,810 units and dumping 44 bbls water/mud. Checked flow- 6.5 barrels per hour. Run in hole through window without issue, continued running in hole with tight spot at 9,910' MD. Washed down last 2 stands and circulated surface to surface once on bottom with 8,046 units max gas and dumping 112 bbls water/mud. Circulating and conditioning mud at time of report. Gas: There was no formation gas or connection gas, maximum trip gas was 9,810 units. Fluids: 0 barrels of mud gained or lost downhole. 8000 8500 9000 9500 10000 10500 11000 11500 12000 12500 0 5 10 15 20 25 30 35 40 45 Me a s u r e d D e p t h Rig Days Prognosed Actual WELL NAME: SCU 41B-04-04 OPERATOR: Hilcorp Alaska, LLC MUD CO: Baroid RIG: Saxon 169 SPERRY JOB: AK-XX-0901916736 Days vs. Depth 19 December 2015 Sperry SDL Arrived on Location LOCATION: Swanson Creek Field AREA: Kenai Peninsula Borough STATE: Alaska SPUD: 8-Apr-2014 TD: 22-Jan-2015 POOH for BOP Test 01 Jan 2015 TD Production Hole Section 11000' MD, 10828' TVD Off Bot: 21:43 03 Jan 2015 Commenced 6" Production Hole Section On Bot: 05:43 17 Jan 2015 Commenced 6" Production Hole Section On Bot: 07:43 25 Dec 2014 TOOH for Bit Change 26 Dec 2014 POOH for new BHA 21 Jan 2015 TD Production Hole Section 11003' MD, 10829' TVD Off Bot: 21:31 22 Jan 2015 Landed 4.5" Liner 10,998' MD, 10,822' TVD 25 Jan 2015 WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Difficulties experienced: The heat trace had electrical wires that were short circuiting which prevented it from heating. We had frozen sample lines which interrupted gas readings. The problem was solved with consultation with the rig electrician. We have had no issues since. However, the moisture in the exhaust from the THC was freezing as it is directed outside the unit. It was causing pressure issues and interrupted gas readings until we plugged it into an extra line in the heat trace. The exhaust now comes out in the pits and we have had no issues since. Our sample oven was not in operating condition so we had a new one sent out. We now have better control of temperature and have a safer environment. We experienced an excess of moisture in the Isotube which needs more attention throughout the well. This will prevent the loss of data and scramble to replace the genie filter and dry out lines/machines. Recommendations: In the future we might want to insulate sample lines between gas equipment to prevent frozen lines, or to use the heat trace if extra lines are available. Innovations and/or cost savings: We will be working on the trap design to allow for more range in depth without having to detach the entire unit. With a longer shaft and a plate with different height brackets, we will be able to adjust the trap more easily and safely as well as prevent the loss of gas data. We had better communication about the sample program which allowed us adequate time to prepare for sample collection, specifically wet samples. The ROC provided excellent documentation on rig ativities as well as maintaining daily communication to make sure any issues were tended to and solved. The ROC provided a news letter highlighting field-wide issues and provided helpful tips and solutions which we may encounter on later jobs. Soldotna Creek Unit 41B-04 Swanson River Field Hilcorp Alaska, LLC AK-AM-0901916736 Alaska Saxon 169 6" Production Hole Jane Grundin 9-Jan-2014 What went as, or better than, planned: Kenai Peninsula Borough Surface Data Logging After Action Review WELL NAME:LOCATION: OPERATOR:AREA:Kenai Peninsula Borough SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 We had no issues with gas equipment, Insite, or Pason. Soldotna Creek Unit 41B-04 Swanson River Field Hilcorp Alaska, LLC AK-AM-090196736 Alaska Saxon 169 Production Jane Grundin 16-Feb-2015 What went as, or better than, planned: Difficulties experienced: No data was lost during drilling and everything went as planned. Recommendations: Keep paperwork up to date, calibrate gas equipment often, and keep work areas clean to continue smooth operations. Innovations and/or cost savings: N/A Surface Data Logging After Action Review Soldotna Creek Unit 41B-04 Hilcorp Alaska, LLC Baroid Saxon 169 AK-XX-0901916736 Date Depth Wt Vis PV YP Gels Filt R600/R300/R200/R100/ R6/R3 Cake Solids Oil/Water Sd Pm pH MBT Pf/Mf Chlor Hard ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds %%%ppb Eqv mg/l Ca++ 20-Dec 10758 8.45 30 ----------6.8 --13000 3440 RIH Scraper Run 21-Dec 10758 8.45 30 ----------6.8 --13000 3440 TOOH 22-Dec 10758 8.45 30 ----------6.8 --13000 3440 Wireline CIBP 23-Dec 9086 9.80 56 10 16 5/8/10 5.6 36/26/21/16/6/4 1/2 5.5 0.0/91.9 -0.50 9.9 2.8 0.20/1.00 33000 100 Shearing Whipstock 24-Dec 9089 9.80 59 11 18 5/8/11 5.1 40/29/24/18/6/5 1/2 6.4 0.0/90.9 0.10 0.45 9.8 2.5 0.20/3.00 33500 60 Preping to P/U BHA 25-Dec 9092 9.80 60 13 19 6/8/11 5.2 45/32/26/20/7/5 1/2 6.5 0.0/91.0 0.10 0.50 9.9 2.3 0.15/2.00 31500 60 Drilling 6" Prodcution Hole 26-Dec 9109 9.80 51 12 18 5/7/10 4.9 42/30/25/18/6/5 1/2 6.3 0.0/91.0 0.10 0.65 10.2 1.8 0.45/3.20 34000 60 TOOH 27-Dec 9108 9.90 59 12 21 6/8/11 4.4 45/33/27/20/7/5 1/2 6.7 0.0/90.6 0.10 0.50 10.1 1.5 0.24/2.70 34000 80 Drilling 6" Prodcution Hole 28-Dec 9151 9.80 57 14 19 5/7/10 4.4 47/33/27/22/6/5 1/2 6.4 0.0/90.9 0.10 0.50 10.2 1.5 0.20/2.00 33500 40 POOH w/wireline 29-Dec 9466 9.80 49 13 20 5/7/10 4.4 46/33/27/19/6/4 1/2 6.6 0.0/90.9 0.10 0.40 9.6 2.0 0.15/3.00 32000 60 Drilling 6" Production Hole 30-Dec 10082 10.60 49 14 20 5/7/10 3.7 48/34/27/19/6/4 1/2 10.1 0.0/87.6 0.10 0.35 9.5 2.3 0.25/3.50 30000 40 Drilling 6" Production Hole 31-Dec 10274 11.00 47 13 20 6/9/12 4.2 46/33/27/20/6/5 1/2 11.1 0.0/86.3 0.10 0.20 8.8 2.3 0.25/3.80 34000 40 POOH for BOP Test 1-Jan 10274 10.98 47 12 22 7/9/12 4.8 46/34/28/20/6/5 1/2 11.0 1.0/86.5 0.10 0.30 9.6 2.3 0.50/3.80 33000 60 L/D Packer Date Depth Wt Vis PV YP Gels Filt R600/R300/R200/R100/ R6/R3 Cake Solids Oil/Water Sd Pm pH MBT Pf/Mf Chlor Hard ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds %%%ppb Eqv mg/l Ca++ 2-Jan 10294 10.6 49 11 17 5/7/11 5.0 39/28/23/17/6/4 1/2 9.0 0.0/88.4 0.10 0.40 9.9 2.0 0.30/3.10 34000 80 Drilling 6" Production Hole 3-Jan 11000 10.6 46 14 20 5/8/11 4.0 48/34/28/20/6/4 1/2 9.1 0.0/88.3 0.10 1.20 10.9 2.0 0.70/2.40 34000 80 TOOH 4-Jan 11000 10.65 49 13 21 6/10/13 4.4 47/35/29/21/7/5 1/2 9.4 0.0/88.0 0.10 1.10 10.1 2.0 0.50/2.80 34000 80 P/U MWD Tools 5-Jan 11000 10.6 50 12 22 6/10/12 4.6 46/34/28/20/7/5 1/2 9.2 0.0/88.2 0.10 0.60 9.7 2.0 0.25/3.00 34000 40 L/D BHA 6-Jan 11000 10.65 49 12 19 6/9/12 4.8 43/31/26/19/6/4 1/2 9.3 0.0/88.1 0.10 0.60 10.2 2.0 0.60/4.10 34000 40 Re-milling Window 7-Jan 11000 10.65 49 12 20 5/8/11 4.7 44/32/26/19/6/4 1/2 9.3 0.0/88.1 0.10 0.75 9.5 2.0 0.30/4.80 34000 60 Washing to Bottom 8-Jan 11000 10.8 50 13 20 6/9/13 4.5 46/33/28/21/7/5 1/2 10.1 0.0/87.4 0.15 0.20 8.9 2.5 0.15/4.00 32500 90 R/U 4.5" Production Liner 9-Jan 11000 10.8 47 11 19 5/8/11 5.1 41/30/25/18/6/5 1/2 10.2 0.0/87.4 0.10 0.70 9.9 2.5 0.40/5.00 31500 80 R/U New Liner Tools 10-Jan 11000 10.8 46 11 19 5/8/11 5.0 41/30/25/19/6/5 1/2 10.2 0.0/87.5 0.15 0.35 9.3 2.5 0.40/5.20 30000 60 RIH to Re-Mill Window 11-Jan 11000 10.85 45 11 18 5/8/11 5.6 40/29/25/18/6/5 1/2 10.5 0.0/87.3 0.15 0.10 8.3 2.5 0.05/4.00 29000 60 M/U Cleanout BHA 12-Jan 11000 10.8 45 10 19 5/7/11 5.1 39/29/24/18/6/4 1/2 10.2 0.0/87.4 0.15 0.35 9.3 2.5 0.20/5.00 31500 80 POOH w/ clean out BHA 13-Jan 11000 10.8 43 13 19 6/8/12 4.5 45/32/27/20/7/5 1/2 10.3 0.0/87.4 0.10 0.15 8.8 2.5 0.10/4.50 30500 70 POOH w/ Milling Assy 14-Jan 11000 10.8 43 11 18 5/7/9 5.4 40/29/24/18/6/4 1/2 10.3 0.0/87.4 0.10 0.25 9.0 2.5 0.10/4.30 30500 80 Milling Open Hole 15-Jan 11000 10.8 46 12 19 5/7/9 5.1 43/31/26/19/6/4 1/2 10.3 0.0/87.4 0.1 0.10 9.2 2.5 0.20/4.50 30000 100 Testing BOP 16-Jan 11000 10.8 46 12 19 5/8/10 5.0 43/31/26/19/6/4 1/2 10.3 0.0/87.4 0.1 0.10 8.6 2.5 0.12/5.00 30000 120 RIH w/ Directional 17-Jan 11000 10.8 42 11 19 5/7/9 5.8 41/30/25/18/6/4 1/2 10.2 0.0/87.5 0.1 0.20 9.0 2.5 0.20/5.50 30000 100 Drilling Ahead 18-Jan 9261 10.8 48 12 18 4/5/7 4.8 42/30/24/17/5/4 1/2 10.5 0.0/87.2 0.1 0.40 9.4 2.5 0.40/5.50 30500 60 Drilling 6" Production Hole 19-Jan 9394 10.8 45 13 18 4/6/7 4.0 44/31/25/18/5/4 1/2 10.4 0.0/87.3 0.1 0.35 9.3 2.5 0.35/6.20 32000 70 Drilling 6" Production Hole 20-Jan 9581 10.8 43 12 18 4/5/7 5.0 42/30/24/18/5/4 1/2 10.6 0.0/87.0 0.1 0.40 9.2 2.5 0.50/6.30 32000 80 L/D BHA 21-Jan 9658 10.8 47 13 18 4/5/8 5.2 44/31/25/18/5/4 1/2 10.5 0.0/87.2 0.1 1.25 9.9 2.5 1.05/7.60 30500 80 Drilling 6" Production Hole 22-Jan 11003 10.85 53 17 19 4/6/8 4.2 53/36/29/21/6/4 1/2 10.6 0.0/87.0 0.1 0.90 9.8 2.5 1.00/6.00 31000 60 POOH / Madpass 23-Jan 11003 10.8 48 14 19 4/6/8 4.6 47/33/28/20/5/4 1/2 10.8 0.0/87.0 0.1 0.30 8.7 2.5 0.15/4.50 29000 60 POOH L/D BHA 24-Jan 11003 10.85 48 12 17 4/6/8 4.8 41/29/24/18/5/4 1/2 10.6 0.0/87.2 0.1 0.50 9.4 2.5 0.40/5.00 29000 60 Circulating Casing Record Remarks 13.625" Casing @ 3000' MD, 3000'TVD 7" Casing @ 9055' MD, 9055'TVD 4.5" Casing @ 10998' MD, 10822'TVD Remarks WELL NAME:LOCATION:Swanson River Field OPERATOR:AREA:Kenai Peninsula Borough MUD CO:STATE:Alaska RIG:SPUD:8-Apr-2014 SPERRY JOB:TD:22-Jan-2015 W a t e r a n d O i l B a s e d M u d R e c o r d BHA#SDL RUN #Bit #Bit Type Bit Size Depth In Depth Out Footage Bit Hours TFA AVG ROP WOB (max) RPM (max) SPP (max) FLOW GPM (max)Bit Grade Comments 1 200 1 PDC 6.00 9089 9109 20 7.76 0.464 3.0 11 -2200 265 2-7-BT-G-X-N-PN-PR Clean out Run 2 400 2 PDC 6.00 9109 10273 1164 49.13 0.464 56.0 17 80 2610 270 2-2-CT-A-X-1-WT-RIG Drill Production Section 3 500 3 PDC 6.00 10273 11000 727 17.99 0.464 40.0 8 90 2475 260 2-3-BT-G-X-I-CT-TD TD Production Section 14 1000 5 PDC 6.00 9055 9581 526 77.47 0.460 10.0 18 80 2510 250 2-3-CT-A-X-1-JD-PR Clean out run 15 1100 6 Smith MDi513 PDC 6.00 9582 9908 326 33.77 0.451 27.0 10 60 2300 240 1-2-CT-A-X-I-JD-TD Clean out run into previous wellbore Alaska RIG:Saxon 169 SPUD:8-Apr-2014 WELL NAME:Soldotna Creek Unit 41B-04 LOCATION:Swanson River Field OPERATOR:Hilcorp Alaska, LLC AREA:Kenai Peninsula Borough MUD CO: SPERRY JOB:AK-XX-0901916736 TD:22-Jan-2015 Baroid STATE: B i t R e c o r d . . * 24 hr Recap: RIH w/cement bails and dumped them on the CIBP. Capped the bails w/mud. R/D Wireline, well taking ~20 bph Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 13000 - 20-Dec-2014 23:59 Current Pump & Flow Data: 0 Max ROP ROP (ft/hr) 3.07 @ Mud Data Depth Morning Report Report # 1 Customer: Well: Area: Location: Rig: SCU 41B-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: ConditionBit # --8.45 Size Geology: N/A Fluids: -335 bbls PW Max Gas: N/A 9346' 6489' 100% Gas In Air=10,000 Units-Connection - Tools N/A API FL Chromatograph (ppm) WOB Production N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min -Background (max)Trip Average - Mud Type Lst Production Type Produced Water -10758'- Depth in / out YP (lb/100ft2) 6.80 --- -- CementChtSd C-4i C-4n 24 hr Max 26.0 Weight - Hours C-3 Sst (ppb Eq) C-1 C-5i Scraper RIH PV Footage J. Grubb / D. Yessak ShClyst TuffGvlCoal cP - 29.0 Gas Summary - -- (current) Avg to- Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) N/A 10758' N/A Max @ ft Current -- Date: Time: produced water. M/U scraper assembly, P/U singles and RIH at time of report. - in --Minimum Depth C-5n - - C-2 - SPP (psi) Gallons/stroke TFABit Type Depth -30 N-80 MBT - pH - - - Siltst 7.00'' 0 0 Units* Casing Summary Lithology (%) -- - 907-283-1309Unit Phone: - Jane Grundin Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs Set AtSize 29.0 N-80 Grade N-809383' 7.00'' 7.00'' (max)(current) Production - - Cly - . . * 24 hr Recap: (max)(current) Production - - Cly - Set AtSize 29.0 N-80 Grade N-809383' 7.00'' 7.00'' 907-283-1309Unit Phone: - Jane Grundin Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs - - 7.00'' 0 0 Units* Casing Summary Lithology (%) - N-80 MBT - pH - - - Siltst SPP (psi) Gallons/stroke TFABit Type Depth -30 C-5n - - C-2 - in --Minimum Depth Time: RIH w/2 7/8" tubing T/937' MD. RIH w/4 1/2" DP T/9,495' MD and tested RTTS. Pressured up front side and lost pressure. - N/A 10758' 10758' Max @ ft Current -- Date: Avg to- Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 29.0 Gas Summary - -- (current) J. Grubb / D. Yessak ShClyst TuffGvlCoal cP - Footage Sst (ppb Eq) C-1 C-5i TOOH PV 24 hr Max 26.0 Weight - Hours C-3 -- CementChtSd C-4i C-4n YP (lb/100ft2) 6.80 --- Produced Water -10758'- Depth in / out Mud Type Lst Production Type Average 30111Background (max)Trip N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min Tools N/A API FL Chromatograph (ppm) WOB Production 100% Gas In Air=10,000 Units-Connection - Geology: N/A Fluids: -294 bbls PW Max Gas: N/A on the back side. TOOH at time of report for new CIBP. Pressured up back side and pressure held. TIH above CIBP @ 10,278' MD where pressure was lost on the front side but held 9346' 6489' ConditionBit # --8.45 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: Morning Report Report # 2 Customer: Well: Area: Location: Rig: SCU 41B-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Field ROP ROP (ft/hr) 3.07 @ Mud Data Depth 21-Dec-2014 23:59 Current Pump & Flow Data: 0 Max - Chlorides mg/l 13000 RIH T/9,379' MD and circulated, well taking ~21 bph. TOOH w/scraper BHA for RTTS. M/U RTTS assembly and Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:TOOH and racked back DP, L/D 2 7/8" tubing. R/U wire line and RIH w/ CIBP. Set CIBP @ 10,297' MD and Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 13000 - 22-Dec-2014 23:59 Current Pump & Flow Data: 0 Max ROP ROP (ft/hr) 3.07 @ Mud Data Depth Morning Report Report # 3 Customer: Well: Area: Location: Rig: SCU 41B-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: ConditionBit # --8.45 Size Geology: N/A Fluids: -155 bbls PW Max Gas: N/A R/U wireline cement bails and dumped 35' cement. P/U CIBP and RIH at time of report. 9346' 6489' 100% Gas In Air=10,000 Units-Connection - Tools N/A API FL Chromatograph (ppm) WOB Production N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max)Trip Average 15 Mud Type Lst Production Type Produced Water -10758'- Depth in / out YP (lb/100ft2) 6.80 --- -- CementChtSd C-4i C-4n 24 hr Max 26.0 Weight - Hours C-3 Sst (ppb Eq) C-1 C-5i Wireline CIBP PV Footage J. Grubb / D. Yessak ShClyst TuffGvlCoal cP - 29.0 Gas Summary - -- (current) Avg to- Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) N/A 10758' 10758' Max @ ft Current -- Date: Time: attempted to test to 2600 psi, tested to 2300 psi. RIH w/ second CIBP T/10,275' MD. Tested CSG to 2600 psi for 30 min, passed. - in --Minimum Depth C-5n - - C-2 - SPP (psi) Gallons/stroke TFABit Type Depth -30 N-80 MBT - pH - - - Siltst 7.00'' 0 0 Units* Casing Summary Lithology (%) -- - 907-283-1309Unit Phone: - Jane Grundin Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs Set AtSize 29.0 N-80 Grade N-809383' 7.00'' 7.00'' (max)(current) Production - - Cly - . . * 24 hr Recap: (max)(current) Production - - Cly - Set AtSize 29.0 N-80 Grade N-809383' 7.00'' 7.00'' 907-283-1309Unit Phone: - Jane Grundin Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs - - 7.00'' 0 0 Units* Casing Summary Lithology (%) - N-80 MBT - pH - - - Siltst SPP (psi) Gallons/stroke TFABit Type Depth 2.856 C-5n - - C-2 - in --Minimum Depth Time: assembly and P/U whipstock. SIH T/793' MD and RIH w/stand from derrick. R/U wireline and RIH. Oriented whipstock and - 0' 9086' - Max @ ft Current -- Date: Avg to- Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 29.0 Gas Summary - -- (current) J. Grubb / D. Yessak ShClyst TuffGvlCoal cP 10 Footage Sst (ppb Eq) C-1 C-5i Shearing Whipstock PV 24 hr Max 26.0 Weight - Hours C-3 -- CementChtSd C-4i C-4n YP (lb/100ft2) 9.90 --- KCL 5.69086'16 Depth in / out Mud Type Lst Production Type Average 270Background (max)Trip N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min Tools N/A API FL Chromatograph (ppm) WOB Production 100% Gas In Air=10,000 Units-Connection - Geology: N/A Fluids: 0 bbls Max Gas: N/A preparing to set at time of report. 9346' 6489' ConditionBit # 5.59.809.80 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: Morning Report Report # 4 Customer: Well: Area: Location: Rig: SCU 41B-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Field ROP ROP (ft/hr) 3.07 @ Mud Data Depth 23-Dec-2014 23:59 Current Pump & Flow Data: 0 Max - Chlorides mg/l 33000 RIH T/9,086' MD and set the CIBP; L/D Wireline. Changed out bottom pipe rams, tested rams. R/U milling Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: (max)(current) Production - - Cly - Set AtSize 29.0 N-80 Grade N-809383' 7.00'' 7.00'' 907-283-1309Unit Phone: - Jane Grundin Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs - - 7.00'' 0 0 Units* Casing Summary Lithology (%) - N-80 MBT - pH - - - Siltst SPP (psi) Gallons/stroke TFABit Type Depth 2.559 C-5n - - C-2 - in --Minimum Depth Time: 9,068'MD. Drilled ahead T/9,089'MD, checked flow-static. Pumped sweep. Collected 118lb of metal shavings. Performed - 9086' 9089' 3' Max @ ft Current -- Date: Avg to- Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 29.0 Gas Summary - -- (current) J. Grubb / D. Yessak ShClyst TuffGvlCoal cP 11 Footage Sst (ppb Eq) C-1 C-5i AK-AM-0901916736 P/U BHA PV 24 hr Max 26.0 Weight - Hours C-3 -- CementChtSd C-4i C-4n YP (lb/100ft2) 9.80 --- KCL 5.19089'18 Depth in / out Mud Type Lst Production Type Average 60Background (max)Trip N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min Tools N/A API FL Chromatograph (ppm) WOB Production 100% Gas In Air=10,000 Units-Connection - Geology: N/A Fluids: 0 bbls Max Gas: N/A time of report. FIT to EMW of 12.5ppg. Pumped dry job, TOOH T/ surface, checked flow-static. Serving Rig and prepping to P/U BHA at 9346' 6489' ConditionBit # 6.49.809.80 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: Morning Report Report # 5 Customer: Well: Area: Location: Rig: SCU 41B-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Field ROP ROP (ft/hr) 3.07 @ Mud Data Depth 24-Dec-2014 23:59 Current Pump & Flow Data: 0 Max - Chlorides mg/l 33500 Set whipstock and sheared. Displaced PW with 9.8ppg mud. Began milling window, TOW 9,055'MD, BOW Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: (max)(current) Production - - Cly - Set AtSize 29.0 N-80 Grade N-809383' 7.00'' 7.00'' 907-283-1309Unit Phone: - Jane Grundin Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs - - 7.00'' 0 0 Units* Casing Summary Lithology (%) - N-80 MBT - pH 0.464 - - - Siltst SPP (psi) Gallons/stroke TFABit Type Depth 2.360 C-5n - - C-2 - in --Minimum Depth Time: to window, slip/cut. P/U side entry sub and R/U wireline. Began drilling w/ gyro, drilling ahead at time of report. - 9089' 9092' 3' Max @ ft Current -- Date: Avg to9089' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 29.0 Gas Summary - -- (current) J. Grubb / D. Yessak ShClyst TuffGvlCoal cP 13 Footage Sst (ppb Eq) C-1 C-5i AK-AM-0901916736 Drilling 6" Production Hole PV 24 hr Max 26.0 Weight - Hours C-3 -- CementChtSd C-4i C-4n YP (lb/100ft2) 9.90 --- KCL 5.29092'19 Depth in / out Mud Type Lst Production Type Average 19376Background (max)Trip N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min Tools Gamma, Res, PWD API FL Chromatograph (ppm) 9089' WOB Production 100% Gas In Air=10,000 Units-Connection - Geology: N/A Fluids: 0 bbls Max Gas: N/A 9346' 6489' ConditionBit # 1 6.5 6 9.80 HDBS MM 55 PDC 9.80 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: Morning Report Report # 6 Customer: Well: Area: Location: Rig: SCU 41B-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Field ROP ROP (ft/hr) 3.07 @ Mud Data Depth 25-Dec-2014 23:59 Current Pump & Flow Data: 0 Max - Chlorides mg/l 31500 Uploaded MWD data, TIH T/5,375' MD. TIH on singles F/5,375' MD - T/6,440' MD. TIH w/ stands from derrick Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Continued drilling w/ gyro. Lost comms w/ tool. R/D wireline and waited on new truck. R/U wireline and Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 34000 0 26-Dec-2014 23:59 Current Pump & Flow Data: 2017 Max ROP ROP (ft/hr) 3.07 @ Mud Data Depth Morning Report Report # 7 Customer: Well: Area: Location: Rig: SCU 41B-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: ConditionBit # 1 6.3 6 9.80 HDBS MM 55 PDC 9.80 Size Geology: N/A Fluids: 0 bbls Max Gas: 77 u for new bit. R/D wireline, pump sweep, pump slug, TOOH at time of report. 9346' 6489' 100% Gas In Air=10,000 Units-Connection 3 Tools Gamma, Res, PWD API FL Chromatograph (ppm) 9089' WOB Production N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min 4Background (max)Trip Average - Mud Type Lst Production Type KCL 4.99109'18 Depth in / out YP (lb/100ft2) 10.20 000 00 CementChtSd C-4i C-4n 24 hr Max 26.0 Weight 0 Hours C-3 Sst (ppb Eq) C-1 C-5i AK-AM-0901916736 TOOH PV Footage R. Pederson/ D. Yessak ShClyst TuffGvlCoal cP 12 29.0 Gas Summary 0 0 0 (current) Avg to9089' Yesterday's Depth: Current Depth: 24 Hour Progress: 15.9 Flow In (gpm) Flow In (spm) 9092' 9109' 17' Max @ ft Current 9104'0.3 Date: Time: RIH. CBU 440u. Drilled ahead F/9,092'MD T/9102'MD. Pumped sweep and drilled ahead T/9,109'MD. Begin TOOH 10 in 2 9098'Minimum Depth C-5n 9104' 0.0 C-2 77 SPP (psi) Gallons/stroke TFABit Type Depth 1.851 N-80 MBT 9109' pH 0.464 0 0 0 Siltst 7.00'' 263 91 Units* Casing Summary Lithology (%) 0726 324 907-283-1309Unit Phone: 0 Lesley Hunter Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs Set AtSize 29.0 N-80 Grade N-809383' 7.00'' 7.00'' (max)(current) Production 9 0 Cly 4769 . . * 24 hr Recap: (max)(current) Production 0 0 Cly 2845 Set AtSize 29.0 N-80 Grade N-809383' 7.00'' 7.00'' 907-283-1309Unit Phone: 0 Lesley Hunter Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs 9109' 2845 0 7.00'' 263 91 Units* Casing Summary Lithology (%) 0 N-80 MBT 9108' pH 0.464 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 1.559 C-5n 9109' 0.0 C-2 3 in 0 9109'Minimum Depth Time: time of report. 3 9109' 9108' -1' Max @ ft Current -- Date: Avg to9109' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 29.0 Gas Summary 0 0 0 (current) R. Pederson/ D. Yessak ShClyst TuffGvlCoal cP 12 20' 6 0.464 Footage Sst (ppb Eq) C-1 C-5i AK-AM-0901916736 Drilling 6" Production PV 24 hr Max 26.0 Weight 0 Hours C-3 00 CementChtSd C-4i C-4n YP (lb/100ft2) 10.10 000 HDBS MM 55 PDC KCL 4.4 9109' 9108'21 Depth in / out Mud Type Lst Production Type Average 5364Background (max)Trip N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min Tools Gamma, Res, PWD API FL Chromatograph (ppm) 9089' 9109' WOB Production 100% Gas In Air=10,000 Units-Connection 0 2 Geology: N/A Fluids: 0 bbls Max Gas: 3 u 9346' 6489' Condition 2-7-BT-G-X-N-PN-PR Bit # 1 6.7 6 9.90 HDBS MM 55 PDC 9.90 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: Morning Report Report # 8 Customer: Well: Area: Location: Rig: SCU 41B-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Field ROP ROP (ft/hr) 3.07 @ Mud Data Depth 27-Dec-2014 23:59 Current Pump & Flow Data: 2019 Max 0 Chlorides mg/l 34000 TOOH T/surface. Swap motor and bit and RIH T/9089' MD. CBU 536u. R/U and RIH w/ wireline. Began drilling at Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Continued drilling w/ gyro F/9,109'MD T/9,115'MD. Pumped sweep. P/U T/9,094'MD and R/D wireline. Drilled ahead Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 33500 0 28-Dec-2014 23:59 Current Pump & Flow Data: 0 Max ROP ROP (ft/hr) 3.07 @ Mud Data Depth Morning Report Report # 9 Customer: Well: Area: Location: Rig: SCU 41B-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: Condition 2-7-BT-G-X-N-PN-PR Bit # 1 6.4 6 9.80 HDBS MM 55 PDC 9.80 Size 2 Geology: 100% Sandstone: lt gry, frm, homog, Qtz, transl-clr, f-med gr, subrnd, mod srt, pr cem, Tf, tr C; NSOFC. Fluids: 0 bbls Max Gas: 187 u POOH w/ wireline at the time of report. 9346' 6489' 100% Gas In Air=10,000 Units-Connection 0 Tools Gamma, Res, PWD API FL Chromatograph (ppm) 9089' 9109' WOB Production N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min 2Background (max)Trip Average - Mud Type Lst 100 Production Type HDBS MM 55 PDC KCL 4.4 9109' 9151'19 Depth in / out YP (lb/100ft2) 10.20 000 00 CementChtSd C-4i C-4n 24 hr Max 26.0 Weight 0 Hours C-3 Sst (ppb Eq) C-1 C-5i AK-AM-0901916736 POOH w/ wireline PV 20' 6 0.464 Footage R. Pederson/ D. Yessak ShClyst TuffGvlCoal cP 14 29.0 Gas Summary 0 0 0 (current) Avg to9089' Yesterday's Depth: Current Depth: 24 Hour Progress: 1944.0 Flow In (gpm) Flow In (spm) 9108' 9151' 43' Max @ ft Current 9141'1.3 Date: Time: F/9,115'MD T/9,128'MD. R/U wireline and continued sliding. Pumped sweep. Continued drilling T/9,151'MD and R/D wireline. 31 in 5 9130'Minimum Depth C-5n 9129' 0.0 C-2 187 SPP (psi) Gallons/stroke TFABit Type Depth 1.557 N-80 MBT 9151' pH 0.464 0 0 0 Siltst 7.00'' 0 0 Units* Casing Summary Lithology (%) 09113' 845 216 907-283-1309Unit Phone: 0 Lesley Hunter Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs Set AtSize 29.0 N-80 Grade N-809383' 7.00'' 7.00'' (max)(current) Production 2 0 Cly 3491 . . * 24 hr Recap: (max)(current) Production 5 0 Cly 6483 70 Set AtSize 29.0 N-80 Grade N-809383' 7.00'' 7.00'' 907-283-1309Unit Phone: 0 Lesley Hunter Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs 4467 1104 7.00'' 267 91 Units* Casing Summary Lithology (%) 0 N-80 MBT 9466' pH 0.464 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 2.049 C-5n 9152' 62.1 C-2 254 in 6 9142'Minimum Depth Time: T/9,166'MD. R/D wireline and drilled ahead T/9,460'MD at time of report. 32 9151' 9466' 315' Max @ ft Current 9346'12.6 Date: Avg to9089' Yesterday's Depth: Current Depth: 24 Hour Progress: 74.4 Flow In (gpm) Flow In (spm) 29.0 10 Gas Summary 0 0 0 (current) R. Pederson/ D. Yessak ShClyst TuffGvlCoal cP 13 20' 6 0.464 Footage Sst (ppb Eq) C-1 C-5i AK-AM-0901916736 Drilling 6' Production PV 24 hr Max 26.0 Weight 0 Hours C-3 00 CementChtSd C-4i C-4n YP (lb/100ft2) 9.60 000 HDBS MM 55 PDC KCL 4.4 9109' 9460'20 Depth in / out Mud Type Lst 20 Production Type Average -33Background (max)Trip N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min Tools Gamma, Res, PWD API FL Chromatograph (ppm) 9089' 9109' WOB Production 100% Gas In Air=10,000 Units402Connection 1 2 Geology: 100% Sand: transl-transp, gy, Qtz, f-c gr w/occ vc Qtz gr, subrnd, subsphr, pr srt, tf, occ hrd Sst, r Pyr; NSOFC. Fluids: 0 bbls Max Gas: 254 u 9346' 6489' Condition 2-7-BT-G-X-N-PN-PR Bit # 1 6.6 6 9.80 HDBS MM 55 PDC 9.80 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: Morning Report Report # 10 Customer: Well: Area: Location: Rig: SCU 41B-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Field ROP ROP (ft/hr) 3.07 @ Mud Data Depth 29-Dec-2014 23:59 Current Pump & Flow Data: 2149 Max 0 Chlorides mg/l 32000 Finished R/D wireline. Drilled ahead rotating F/9,151'MD T/9,161'MD. R/U wireline and RIH. Drilled ahead Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Continued drilling ahead F/ 9,466' MD - T 9,715' MD, checked flow- 14 bph. After seeing 9,534 U CG, weighted up to Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 30000 7 30-Dec-2014 23:59 Current Pump & Flow Data: 2478 Max ROP ROP (ft/hr) 3.09 @ Mud Data Depth Morning Report Report # 11 Customer: Well: Area: Location: Rig: SCU 41B-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: Condition 2-7-BT-G-X-N-PN-PR Bit # 1 10.1 6 10.60 HDBS MM 55 PDC 10.60 Size 2 Geology: 100% Siltstone: med-lt gy, frm, homog, sl tf, wl comp, non calc; NSOFC Fluids: 0 bbls Max Gas: 180 u time of report. 7,083U CG. Weighted up to 10.6 ppg MW. Saw 7,467U CG @ 9,976' MD. Drilled T/10,082, flowing at 16 bph, drilling ahead at T/9,840' MD, checked flow- 10 bph, saw 6,679U CG. Weighted up to 10.4 ppg MW. Drilled T/9,899' MD, checked flow- 20 bph, saw 6489' 4527' 100% Gas In Air=10,000 Units9534Connection 27 Tools Gamma, Res, PWD API FL Chromatograph (ppm) 9089' 9109' WOB Production N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min 9Background (max)Trip Average - Mud Type Lst Production Type HDBS MM 55 PDC KCL 3.7 9109' 10082'20 Depth in / out YP (lb/100ft2) 9.50 000 00 CementChtSd C-4i C-4n 24 hr Max 26.0 Weight 18 Hours C-3 Sst (ppb Eq) C-1 C-5i AK-AM-0901916736 - - Drilling 6' Production PV 20' 6 0.464 Footage R. Pederson/ S. Barber ShClyst TuffGvlCoal cP 14 29.0 Gas Summary 0 0 0 (current) Avg to9089' Yesterday's Depth: Current Depth: 24 Hour Progress: 113.9 Flow In (gpm) Flow In (spm) 9466' 10082' 616' Max @ ft Current 9784'25.5 Date: Time: 10.0 ppg MW. Drilled T/9,779' MD, checked flow- 10 bph, and saw 1,965 units CG. Weighted up to 10.2 ppg MW. Drilled 48 in 1 9694'Minimum Depth C-5n 9800' 34.4 C-2 180 SPP (psi) Gallons/stroke TFABit Type Depth 2.349 N-80 MBT 10082' pH 0.464 0 5 0 Siltst 7.00'' 271 92 Units* Casing Summary Lithology (%) 0 100 6602 48 907-283-1309Unit Phone: 0 Jane Grundin Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs Set AtSize 29.0 N-80 Grade N-809068' 7.00'' 7.00'' (max)(current) Production 76 0 Cly 23020 . . * 24 hr Recap: (max)(current) Production 902 0 Cly 12656 40 Set AtSize 29.0 N-80 Grade N-809068' 7.00'' 7.00'' 907-283-1309Unit Phone: 0 Jane Grundin Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs 60 3049 282 7.00'' 0 0 Units* Casing Summary Lithology (%) 0 N-80 MBT 10274' pH 0.464 0 9 0 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 2.347 C-5n 10256' 0.0 C-2 113 in 6 10135'Minimum Depth Time: srt. up mud to 10.8 ppg, and pulled back T/9,888' MD. Checked flow- 10 bph, ran back to bottom, CBU 7,954U gas, and weighted up 31 10082' 10274' 192' Max @ ft Current 10253'8.9 Date: Avg to9089' Yesterday's Depth: Current Depth: 24 Hour Progress: 292.6 Flow In (gpm) Flow In (spm) 29.0 Gas Summary 0 12 0 (current) R. Pederson/ S. Barber ShClyst TuffGvlCoal cP 13 20' 6 0.464 Footage Sst (ppb Eq) C-1 C-5i AK-AM-0901916736 - - TOOH for BOP Test PV 24 hr Max 26.0 Weight 98 Hours C-3 00 CementChtSd C-4i C-4n YP (lb/100ft2) 8.80 000 HDBS MM 55 PDC KCL 4.2 9109' 10274'20 Depth in / out Mud Type Lst Production Type Average 79543Background (max)Trip N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min Tools Gamma, Res, PWD API FL Chromatograph (ppm) 9089' 9109' WOB Production 100% Gas In Air=10,000 Units7166Connection 149 2 Geology: 60% Siltstone : lt-dk gy, tr brn/blk, mod frm, homog, non calc; NSOFC; 40% Sand : clr-opq, Qtz, vf-f gr, sbrnd, sphr, mod Fluids: 0 bbls Max Gas: 113 u and pumped another 13 ppg pill. Checked flow- 5.3 bph, continuing to TOOH for BOP test at time of report. mud to 11.0 ppg. Checked flow- 6 bph, began TOOH. Checked flow at window- 5.2 bph, pumped 13 ppg pill. TOOH T/3,452' MD 6489' 4527' Condition 2-7-BT-G-X-N-PN-PR Bit # 1 11.1 6 11.00 HDBS MM 55 PDC 11.00 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: Morning Report Report # 12 Customer: Well: Area: Location: Rig: SCU 41B-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Field ROP ROP (ft/hr) 3.09 @ Mud Data Depth 31-Dec-2014 23:59 Current Pump & Flow Data: 0 Max 17 Chlorides mg/l 34000 Drilled ahead F/10,082' MD - T/10,274' MD seeing max CG of 7,166U and flow of 9 bph. Pumped sweep, weighted Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: 7.0 67 2-2-CT-A-X-1-WT-RIG2HDBS MM 55 PDC 6 0.464 49.13 9109' (max)(current) Production - - Cly - Set AtSize 29.0 N-80 Grade N-809068' 7.00'' 7.00'' 907-283-1309Unit Phone: - Jane Grundin Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs - - 7.00'' 0 0 Units* Casing Summary Lithology (%) - N-80 MBT 10274' pH 0.464 - - - Siltst SPP (psi) Gallons/stroke TFABit Type Depth 2.347 C-5n - 0.0 C-2 - in --Minimum Depth Time: R/U to pull packer out. Opened up W/ 11BPH flow, laying down packer at time of report. - 10274' 10274' 0' Max @ ft Current -0.0 Date: Avg to9089' Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) 29.0 Gas Summary - -- (current) R. Pederson/ S. Barber ShClyst TuffGvlCoal cP 12 20' 6 0.464 Footage 7.76 10274' 1165' Sst (ppb Eq) C-1 C-5i AK-AM-0901916736 - - L/D Packer PV 24 hr Max 26.0 Weight - Hours C-3 -- CementChtSd C-4i C-4n YP (lb/100ft2) 9.60 --- - HDBS MM 55 PDC KCL 4.8 10274' 10274'22 Depth in / out Mud Type Lst Production Type Average 63Background (max)Trip N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min Tools Gamma, Res, PWD API FL Chromatograph (ppm) 7.09089' 9109' WOB Production 100% Gas In Air=10,000 Units-Connection - 3 Geology: N/A Fluids: 0 bbls Max Gas: 6 u 6489' 4527' Condition 2-7-BT-G-X-N-PN-PR Bit # 1 11.0 6 10.98 HDBS MM 55 PDC 10.98 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: Morning Report Report # 13 Customer: Well: Area: Location: Rig: SCU 41B-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Field ROP ROP (ft/hr) 3.09 @ Mud Data Depth 1-Jan-2015 23:59 Current Pump & Flow Data: 0 Max - Chlorides mg/l 33000 Finished TOOH, 10BPH flow. RIH with mud motor and bit to 59'MD to isolate during BOP test. Completed BOP test.. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:L/d packer and RIH T/1,630' MD. CBU 1,874U gas, RIH T/2,747' MD, CBU 8,890U gas. RIH T/4,388' MD, CBU Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 34000 124 2-Jan-2015 23:59 Current Pump & Flow Data: 1980 Max ROP ROP (ft/hr) 3.09 @ Mud Data Depth Morning Report Report # 14 Customer: Well: Area: Location: Rig: SCU 41B-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: Condition 2-7-BT-G-X-N-PN-PR Bit # 1 9.0 6 10.55 HDBS MM 55 PDC 10.60 Size 3 Geology: 40% Siltstone : drk brn, sft, ea, non calc; lt gry, frm, homog, tf, non calc; NSOFC; 30% Coal : v drk brn, hrd, splin; 20% Fluids: 0 bbls Max Gas: 116 u Got back on bottom and drilling ahead at time of report. water. RIH T/9,025' MD and CBU 6,740U gas, dumped another 164 bbls. RIH T/9,127' MD and began washing and reaming. 6489' 4527' 100% Gas In Air=10,000 Units-Connection 75 Tools Gamma, Res, PWD API FL Chromatograph (ppm) 7.09089' 9109' WOB Production N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min 14Background (max)Trip Average 9581 Mud Type Lst 10 Production Type - HDBS MM 55 PDC KCL 5.0 10274' 10294'17 Depth in / out 060514 Hours C-3 20 00 Cement PV 24 hr Max 26.0 Weight Sd YP (lb/100ft2) 9.90 1165' Sst (ppb Eq) C-1 C-5i Cht C-4i C-4n Coal cP 11 20' 6 0.464 Footage 7.76 (current) R. Pederson/ S. Barber ShClyst 30 TuffGvl Yesterday's Depth: Current Depth: 24 Hour Progress: 49.2 Flow In (gpm) Flow In (spm) AK-AM-0901916736 - - Drilling 6" Production Hole 0.5 Date: Avg to9089' 29.0 Shale; 10% Sandstone. 9,577U gas and dumped 100 bbls diluted mud and water. RIH T/6,00' MD, CBU 8,523U gas, dumped another 88 bbls mud and 81 10274' 10290' 16' Max @ ft Current Minimum Depth Time: 103' in 26 10283' Gas Summary 0 0 0 C-5n 10285' 18.7 C-2 116 SPP (psi) Gallons/stroke TFABit Type Depth 2.049 N-80 MBT 10209' pH 0.464 23 0 0 Siltst 7.00'' 256 87 Units* Casing Summary Lithology (%) 2 40 6408 2756 907-283-1309Unit Phone: 0 Jane Grundin Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs Set AtSize 29.0 N-80 Grade N-809068' 7.00'' 7.00'' (max)(current) Production 309 95 Cly 9903 7.0 67 2-2-CT-A-X-1-WT-RIG2HDBS MM 55 PDC 6 0.464 49.13 9109' 10274' . . * 24 hr Recap: 7.0 67 2-2-CT-A-X-1-WT-RIG2HDBS MM 55 PDC 6 0.464 49.13 9109' 10274' (max)(current) Production 1210 237 Cly 22190 90 Set AtSize 29.0 N-80 Grade N-809068' 7.00'' 7.00'' 907-283-1309Unit Phone: 186 Jane Grundin Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs 4490 3144 7.00'' 0 0 Units* Casing Summary Lithology (%) 136 N-80 MBT 10918' pH 0.464 260 344 50 Siltst SPP (psi) Gallons/stroke TFABit Type Depth 2.046 C-5n 10640' 0.0 C-2 314 in 8 10318' Gas Summary 10 647 171 Minimum Depth Time: 10611' Called TD. Checked flow, 6.4 bph. TOOH to shoe as wiper trip at time of report. 104 10290' 11000' 710' Max @ ft Current 29.7 Date: Avg to9089' 29.0 Yesterday's Depth: Current Depth: 24 Hour Progress: 91.7 Flow In (gpm) Flow In (spm) AK-AM-0901916736 - - TOOH (current) R. Pederson/ S. Barber ShClyst TuffGvlCoal cP 14 20' 6 0.464 Footage 726' 7.76 1165' Sst (ppb Eq) C-1 C-5i Cht C-4i C-4n PV 24 hr Max 26.0 Weight Sd YP (lb/100ft2) 10.90 408 Hours C-3 695 Cement 9126581 - HDBS MM 55 PDC KCL 4.0 10274' 11000'20 11000' Depth in / out Mud Type Lst 10 Production Type Average 4818Background (max)Trip N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min Tools Gamma, Res, PWD API FL Chromatograph (ppm) 7.09089' 9109' WOB Production 100% Gas In Air=10,000 Units667Connection 1615 3 Geology: 90% Sand : clr-transl, Qtz, vf-med gr, mod srt, subrnd, subsphr, tf, sl; NSOFC; 10% Sandstone. Fluids: 0 bbls Max Gas: 314 u 6489' 4527' Condition 2-7-BT-G-X-N-PN-PR Bit # 1 9.1 6 10.65 HDBS MM 55 PDC 10.60 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: Morning Report Report # 15 Customer: Well: Area: Location: Rig: SCU 41B-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Field ROP ROP (ft/hr) 3.09 @ Mud Data Depth 3-Jan-2015 23:59 Current Pump & Flow Data: 91 Max 540 Chlorides mg/l 34000 Drilled ahead F/10,290' MD - T/10,337' MD and checked flow- 8.5 bph. Drilled T/11,000' MD and pumped sweep. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:RIH to bottom, pumped sweep. Dumped 35 bbls of water/mud and spotted a pill on bottom. TOOH T/9,011' MD Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 34000 - 4-Jan-2015 23:59 Current Pump & Flow Data: 0 Max ROP ROP (ft/hr) 3.09 @ Mud Data Depth Morning Report Report # 16 Customer: Well: Area: Location: Rig: SCU 41B-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: Condition 2-7-BT-G-X-N-PN-PR Bit # 1 9.4 6 10.65 HDBS MM 55 PDC 10.65 Size 3 Geology: N/A Fluids: 0 bbls Max Gas: N/A checked flow- 7.1 bph. L/D BHA and P/U Madpass tools at time of report. 6489' 4527' 100% Gas In Air=10,000 Units-Connection - Tools Gamma, Res, PWD API FL Chromatograph (ppm) 7.09089' 9109' WOB Production N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min 12Background (max)Trip Average 45 Mud Type Lst Production Type - HDBS MM 55 PDC KCL 4.4 10274' 11000'23 11000' Depth in / out ---- Hours C-3 -- Cement PV 24 hr Max 26.0 Weight Sd YP (lb/100ft2) 10.10 1165' Sst (ppb Eq) C-1 C-5i Cht C-4i C-4n Coal cP 12 20' 6 0.464 Footage 726' 7.76 (current) R. Pederson/ S. Barber ShClyst TuffGvl Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) AK-AM-0901916736 - - P/U MWD Tools - Date: Avg to9089' 29.0 and spotted another pill. TOOH T/5,283' MD and pumped dry job. Checked flow- 2.8 bph. , TOOH leaving the BHA in the hole, - 11000' 11000' 0' Max @ ft Current Minimum Depth Time: - in -- Gas Summary - -- C-5n - - C-2 - SPP (psi) Gallons/stroke TFABit Type Depth 2.049 N-80 MBT 10918' pH 0.464 - - - Siltst 7.00'' 0 0 Units* Casing Summary Lithology (%) -- - 907-283-1309Unit Phone: - Jane Grundin Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs Set AtSize 29.0 N-80 Grade N-809068' 7.00'' 7.00'' (max)(current) Production - - Cly - 7.0 67 2-2-CT-A-X-1-WT-RIG2HDBS MM 55 PDC 6 0.464 49.13 9109' 10274' . . * 24 hr Recap: 7.0 67 2-2-CT-A-X-1-WT-RIG2HDBS MM 55 PDC 6 0.464 49.13 9109' 10274' (max)(current) Production - - Cly - Set AtSize 29.0 N-80 Grade N-809068' 7.00'' 7.00'' 907-283-1309Unit Phone: - Jane Grundin Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs - - 7.00'' 0 0 Units* Casing Summary Lithology (%) - N-80 MBT 10918' pH 0.464 - - - Siltst SPP (psi) Gallons/stroke TFABit Type Depth 2.050 C-5n - - C-2 - in -- Gas Summary - -- Minimum Depth Time: - CBU 9,880U of gas, dumped 143 bbls of water/mud. Couldn't get through window, spotted a pill @ 9,035' MD. Dropped rabbit on - 11000' 11000' 0' Max @ ft Current - Date: Avg to9089' 29.0 Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) AK-AM-0901916736 - - L/D BHA (current) R. Pederson/ S. Barber ShClyst TuffGvlCoal cP 12 20' 6 0.464 Footage 726' 7.76 1165' Sst (ppb Eq) C-1 C-5i Cht C-4i C-4n PV 24 hr Max 26.0 Weight Sd YP (lb/100ft2) 9.70 - Hours C-3 -- Cement --- - HDBS MM 55 PDC KCL 4.6 10274' 11000'22 11000' Depth in / out Mud Type Lst Production Type Average 98806Background (max)Trip N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min Tools Gamma, Res, PWD API FL Chromatograph (ppm) 7.09089' 9109' WOB Production 100% Gas In Air=10,000 Units-Connection - 3 Geology: N/A Fluids: 0 bbls Max Gas: N/A wire down DP, and TOOH to inspect BHA. Checked flow @ 5,876' MD- 1.5 bph. L/D BHA at time of report. 6489' 4527' Condition 2-7-BT-G-X-N-PN-PR Bit # 1 9.2 6 10.60 HDBS MM 55 PDC 10.60 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: Morning Report Report # 17 Customer: Well: Area: Location: Rig: SCU 41B-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Field ROP ROP (ft/hr) 3.09 @ Mud Data Depth 5-Jan-2015 23:59 Current Pump & Flow Data: 0 Max - Chlorides mg/l 34000 RIH w/ MWD tools T/4,066' MD and checked flow- 5 bph. RIH T/7,165' MD, cvhecked flow- 9.8 bph. RIH T/9,034' MD. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:L/D BHA, checked flow- 9.2 bph. Plan to re-mill window, P/U milling assembly and began RIH. Circ S-S 9,882U gas Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 34000 - 6-Jan-2015 23:59 Current Pump & Flow Data: 110 Max 2-3-BT-G-X-I-CT-TD ROP ROP (ft/hr) 3.09 @ Mud Data Depth Morning Report Report # 18 Customer: Well: Area: Location: Rig: SCU 41B-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: Condition 2-7-BT-G-X-N-PN-PR Bit # 1 9.3 6 10.60 HDBS MM 55 PDC 10.65 Size 3 Geology: N/A Fluids: 0 bbls Max Gas: N/A window and cleaning it up at time of report. and RIH T/6,601' MD. Checked flow- 11.8 bph, RIH T/9,020' MD, dumped 134 bbls water/mud, and RIH T/window. Began milling 6489' 4527' 100% Gas In Air=10,000 Units-Connection - Tools Gamma, Res, PWD API FL Chromatograph (ppm) 8 7.09089' 9109' WOB Production N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min 45Background (max)Trip Average 9882 Mud Type Lst Production Type 74 - HDBS MM 55 PDC KCL 4.8 10273' 11000'19 11000' Depth in / out ---- Hours C-3 -- Cement PV 24 hr Max 26.0 Weight Sd YP (lb/100ft2) 10.20 1164' Sst (ppb Eq) C-1 C-5i Cht C-4i C-4n Coal cP 12 20' 6 0.464 Footage 17.99 727' 7.76 (current) J. Grubb/ S. Barber ShClyst TuffGvl Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) AK-AM-0901916736 - - Re-milling Window - Date: Avg to9089' 29.0 @ 4,901' MD and dumped 33 bbls water/mud. Checked flow- 18 bph and continued RIH T/6,067' MD. Dumped 88 bbls water/mud - 11000' 11000' 0' Max @ ft Current Minimum Depth Time: - in -- Gas Summary - -- C-5n - - C-2 - SPP (psi) Gallons/stroke TFABit Type Depth 2.049 N-80 MBT 10918' pH 0.464 - - - Siltst 7.00'' 0 0 Units* Casing Summary Lithology (%) -- - 907-283-1309Unit Phone: - Jane Grundin Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs Set AtSize 29.0 N-80 Grade N-809068' 7.00'' 7.00'' (max)(current) Production - - Cly - 7.0 67 2-2-CT-A-X-1-WT-RIG2HDBS MM 55 PDC 6 0.464 49.13 9109' 10273' . . * 24 hr Recap: 7.0 67 2-2-CT-A-X-1-WT-RIG2HDBS MM 55 PDC 6 0.464 49.13 9109' 10273' (max)(current) Production - - Cly - Set AtSize 29.0 N-80 Grade N-809068' 7.00'' 7.00'' 907-283-1309Unit Phone: - Jane Grundin Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs - - 7.00'' 215 73 Units* Casing Summary Lithology (%) - N-80 MBT 10918' pH 0.464 - - - Siltst SPP (psi) Gallons/stroke TFABit Type Depth 2.047 C-5n - - C-2 - in -- Gas Summary - -- Minimum Depth Time: - checked flow- 1.8 bph. TOOH T/4,350' MD, checked flow- 2.2 bph, and finished TOOH. L/D BHA, checked flow- 4.2 bph, and P/U - 11000' 11000' 0' Max @ ft Current - Date: Avg to9089' 29.0 Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) AK-AM-0901916736 - - Washing to bottom (current) J. Grubb/ S. Barber ShClyst TuffGvlCoal cP 12 20' 6 0.464 Footage 17.99 727' 7.76 1164' Sst (ppb Eq) C-1 C-5i Cht C-4i C-4n PV 24 hr Max 26.0 Weight Sd YP (lb/100ft2) 9.50 - Hours C-3 -- Cement --- 74 - HDBS MM 55 PDC KCL 4.7 10273' 11000'20 11000' Depth in / out Mud Type Lst Production Type Average 987617Background (max)Trip N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min Tools Gamma, Res, PWD API FL Chromatograph (ppm) 8 7.09089' 9109' WOB Production 100% Gas In Air=10,000 Units-Connection - 3 Geology: N/A Fluids: 0 bbls Max Gas: N/A RIH T/9,075' MD and began washing/reaming. Continuing to wash down at time of report. clean out assembly. RIH T/964' MD and checked flow- 5.8 bph. RIH T/9,037' MD and circulated, dumping 57 bbls water/mud. 6489' 4527' Condition 2-7-BT-G-X-N-PN-PR Bit # 1 9.3 6 10.65 HDBS MM 55 PDC 10.65 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: Morning Report Report # 19 Customer: Well: Area: Location: Rig: SCU 41B-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Field 2-3-BT-G-X-I-CT-TD ROP ROP (ft/hr) 3.09 @ Mud Data Depth 7-Jan-2015 23:59 Current Pump & Flow Data: 1250 Max - Chlorides mg/l 34000 Finished re-milling window and checked flow- 2.6 bph. POOH T/9,023' MD, circulated and slip/cut. Spotted pill and Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Washed and reamed to bottom seeing max gas of 8,708U. Checked flow@ 10,466' MD- 11.8 bph. Pumped sweep Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 32500 - 8-Jan-2015 23:59 Current Pump & Flow Data: 0 Max 2-3-BT-G-X-I-CT-TD ROP ROP (ft/hr) 3.09 @ Mud Data Depth Morning Report Report # 20 Customer: Well: Area: Location: Rig: SCU 41B-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: Condition 2-7-BT-G-X-N-PN-PR Bit # 1 10.1 6 10.80 HDBS MM 55 PDC 10.80 Size 3 Geology: N/A Fluids: 0 bbls Max Gas: N/A flow- 0.8 bph. TOOH to surface, L/D BHA, and R/U to run 4.5" production liner at time of report. weighting up mud from 10.6 ppg to 10.8 ppg. TOOH to window and checked flow- 0.6 bph. Spotted 13 ppg mud cap and checked 6489' 4527' 100% Gas In Air=10,000 Units-Connection - Tools Gamma, Res, PWD API FL Chromatograph (ppm) 8 7.09089' 9109' WOB Production N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min 2Background (max)Trip Average 9065 Mud Type Lst Production Type 74 - HDBS MM 55 PDC KCL 4.5 10273' 11000'20 11000' Depth in / out ---- Hours C-3 -- Cement PV 24 hr Max 26.0 Weight Sd YP (lb/100ft2) 8.90 1164' Sst (ppb Eq) C-1 C-5i Cht C-4i C-4n Coal cP 13 20' 6 0.464 Footage 17.99 727' 7.76 (current) J. Grubb/ S. Barber ShClyst TuffGvl Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) AK-AM-0901916736 - - R/U 4.5" Liner - Date: Avg to9089' 29.0 and CBU 9,065U of gas. Checked flow- 9.3 bph. Conducted 1000' wiper trip and ran back to bottom, pumped sweep, and began - 11000' 11000' 0' Max @ ft Current Minimum Depth Time: - in -- Gas Summary - -- C-5n - - C-2 - SPP (psi) Gallons/stroke TFABit Type Depth 2.550 N-80 MBT 10918' pH 0.464 - - - Siltst 7.00'' 0 0 Units* Casing Summary Lithology (%) -- - 907-283-1309Unit Phone: - Jane Grundin Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs Set AtSize 29.0 N-80 Grade N-809068' 7.00'' 7.00'' (max)(current) Production - - Cly - 7.0 67 2-2-CT-A-X-1-WT-RIG2HDBS MM 55 PDC 6 0.464 49.13 9109' 10273' . . * 24 hr Recap: 7.0 67 2-2-CT-A-X-1-WT-RIG2HDBS MM 55 PDC 6 0.464 49.13 9109' 10273' (max)(current) Production - - Cly - Set AtSize 29.0 N-80 Grade N-809068' 7.00'' 7.00'' 907-283-1309Unit Phone: - Jane Grundin Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs - - 7.00'' 0 0 Units* Casing Summary Lithology (%) - N-80 MBT 10918' pH 0.464 - - - Siltst SPP (psi) Gallons/stroke TFABit Type Depth 2.547 C-5n - - C-2 - in -- Gas Summary - -- Minimum Depth Time: - Saw max gas of 9,152U, dumped 77 bbl water/mud. Could not make it through window, decided we would POOH. CBU 4,601U - 11000' 11000' 0' Max @ ft Current - Date: Avg to9089' 29.0 Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) AK-AM-0901916736 - - RIH W/ new liner tools (current) J. Grubb/ S. Barber ShClyst TuffGvlCoal cP 11 20' 6 0.464 Footage 17.99 727' 7.76 1164' Sst (ppb Eq) C-1 C-5i Cht C-4i C-4n PV 24 hr Max 26.0 Weight Sd YP (lb/100ft2) 9.90 - Hours C-3 -- Cement --- 74 - HDBS MM 55 PDC KCL 5.1 10273' 11000'19 11000' Depth in / out Mud Type Lst Production Type Average 91515Background (max)Trip N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min Tools Gamma, Res, PWD API FL Chromatograph (ppm) 8 7.09089' 9109' WOB Production 100% Gas In Air=10,000 Units-Connection - 3 Geology: N/A Fluids: 0 bbls Max Gas: N/A to RIH at time of report. of gas, spotted 13.5 ppg mud cap, and checked flow- static. Began POOH T/surface, M/U new liner running tool, and preparing 6489' 4527' Condition 2-7-BT-G-X-N-PN-PR Bit # 1 10.2 6 10.80 HDBS MM 55 PDC 10.80 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: Morning Report Report # 21 Customer: Well: Area: Location: Rig: SCU 41B-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Field 2-3-BT-G-X-I-CT-TD ROP ROP (ft/hr) 3.09 @ Mud Data Depth 9-Jan-2015 23:59 Current Pump & Flow Data: 0 Max - Chlorides mg/l 31500 Finished R/U liner, M/U shoe track, and checked flow- 5.5 bph. RIH w/4.5" production liner T/9,048' MD and CBU. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:RIH w/ new liner running tool T/2,371' MD, checked flow- 5 bph. RIH T/6,790' MD, CBU 9,625U gas and dumped Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 30000 - 10-Jan-2015 23:59 Current Pump & Flow Data: 0 Max 2-3-BT-G-X-I-CT-TD ROP ROP (ft/hr) 3.09 @ Mud Data Depth Morning Report Report # 22 Customer: Well: Area: Location: Rig: SCU 41B-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: Condition 2-7-BT-G-X-N-PN-PR Bit # 1 10.2 6 10.80 HDBS MM 55 PDC 10.80 Size 3 Geology: N/A Fluids: 0 bbls Max Gas: N/A water/mud. Continuing to RIH @ 4,977' MD at time of report. M/U milling BHA, and begin RIH T/2,183' MD. CBU 5,812U of gas. RIH T/3,739' MD and CBU 9,817U of gas and dumped 38 bbls 6489' 4527' 100% Gas In Air=10,000 Units-Connection - Tools Gamma, Res, PWD API FL Chromatograph (ppm) 8 7.09089' 9109' WOB Production N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min 197Background (max)Trip Average 9817 Mud Type Lst Production Type 74 - HDBS MM 55 PDC KCL 5.0 10273' 11000'19 11000' Depth in / out ---- Hours C-3 -- Cement PV 24 hr Max 26.0 Weight Sd YP (lb/100ft2) 9.30 1164' Sst (ppb Eq) C-1 C-5i Cht C-4i C-4n Coal cP 11 20' 6 0.464 Footage 17.99 727' 7.76 (current) J. Grubb/ S. Barber ShClyst TuffGvl Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) AK-AM-0901916736 - - RIH to Re-Mill Window - Date: Avg to9089' 29.0 35 bbls water/mud. Attached fish and POOH w/fish, checked flow- 0.5 bph. POOH T/surface, L/D liner, and checked flow- 9.7 bph. - 11000' 11000' 0' Max @ ft Current Minimum Depth Time: - in -- Gas Summary - -- C-5n - - C-2 - SPP (psi) Gallons/stroke TFABit Type Depth 2.546 N-80 MBT 10918' pH 0.464 - - - Siltst 7.00'' 0 0 Units* Casing Summary Lithology (%) -- - 907-283-1309Unit Phone: - Jane Grundin Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs Set AtSize 29.0 N-80 Grade N-809068' 7.00'' 7.00'' (max)(current) Production - - Cly - 7.0 67 2-2-CT-A-X-1-WT-RIG2HDBS MM 55 PDC 6 0.464 49.13 9109' 10273' . . * 24 hr Recap: 7.0 67 2-2-CT-A-X-1-WT-RIG2HDBS MM 55 PDC 6 0.464 49.13 9109' 10273' (max)(current) Production - - Cly - Set AtSize 29.0 N-80 Grade N-809068' 7.00'' 7.00'' 907-283-1309Unit Phone: - Jane Grundin Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs - - 7.00'' 0 0 Units* Casing Summary Lithology (%) - N-80 MBT 10918' pH 0.464 - - - Siltst SPP (psi) Gallons/stroke TFABit Type Depth 2.545 C-5n - - C-2 - in -- Gas Summary - -- Minimum Depth Time: - 78 bbls of water. RIH T/9,021' MD, CBU 9,172U of gas and dumped 106 bbls of water. Re-dressed window per Baker rep- - 11000' 11000' 0' Max @ ft Current - Date: Avg to9089' 29.0 Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) AK-AM-0901916736 - - M/U Cleanout BHA (current) J. Grubb/ S. Barber ShClyst TuffGvlCoal cP 11 20' 6 0.464 Footage 17.99 727' 7.76 1164' Sst (ppb Eq) C-1 C-5i Cht C-4i C-4n PV 24 hr Max 26.0 Weight Sd YP (lb/100ft2) 8.30 - Hours C-3 -- Cement --- 74 - HDBS MM 55 PDC KCL 5.6 10273' 11000'18 11000' Depth in / out Mud Type Lst Production Type Average 98801Background (max)Trip N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min Tools Gamma, Res, PWD API FL Chromatograph (ppm) 8 7.09089' 9109' WOB Production 100% Gas In Air=10,000 Units-Connection - 3 Geology: N/A Fluids: 0 bbls Max Gas: N/A 1.3 bph. TOOH w/ milling assembly, checked flow- 2.6 bph. M/U cleanout BHA at time of report. collected 54 bbl of metal shavings. Pumped sweep, pulled 1 stand and pumped 13 ppg mud cap. Slip/cut drill line, checked flow- 6489' 4527' Condition 2-7-BT-G-X-N-PN-PR Bit # 1 10.5 6 10.85 HDBS MM 55 PDC 10.85 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: Morning Report Report # 23 Customer: Well: Area: Location: Rig: SCU 41B-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Field 2-3-BT-G-X-I-CT-TD ROP ROP (ft/hr) 3.09 @ Mud Data Depth 11-Jan-2015 23:59 Current Pump & Flow Data: 0 Max - Chlorides mg/l 29000 RIH T/5,282' MD, CBU 9,880U of gas, dumping 65 bbls of water. RIH T/6,851' MD, CBU 7,222U of gas and dumped Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:RIH w/ cleanout BHA T/9,006' MD. CBU 9,861U of gas and dumped 41 bbls of water/mud. RIH T/9,068' MD and Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 31500 - 12-Jan-2015 23:59 Current Pump & Flow Data: 0 Max 2-3-BT-G-X-I-CT-TD ROP ROP (ft/hr) 3.09 @ Mud Data Depth Morning Report Report # 24 Customer: Well: Area: Location: Rig: SCU 41B-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: Condition 2-7-BT-G-X-N-PN-PR Bit # 1 10.2 6 10.80 HDBS MM 55 PDC 10.80 Size 3 Geology: N/A Fluids: 0 bbls Max Gas: N/A POOH T/ surface, POOH @ 1,517' MD at time of report. through open hole, could not. Decided to POOH. Checked flow- 2 bph, pumped 13 ppg mud cap, and checked flow- 3 bph. Began 6489' 4527' 100% Gas In Air=10,000 Units-Connection - Tools Gamma, Res, PWD API FL Chromatograph (ppm) 8 7.09089' 9109' WOB Production N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min 1Background (max)Trip Average 9861 Mud Type Lst Production Type 74 - HDBS MM 55 PDC KCL 5.1 10273' 11000'19 11000' Depth in / out ---- Hours C-3 -- Cement PV 24 hr Max 26.0 Weight Sd YP (lb/100ft2) 9.30 1164' Sst (ppb Eq) C-1 C-5i Cht C-4i C-4n Coal cP 10 20' 6 0.464 Footage 17.99 727' 7.76 (current) J. Grubb/ S. Barber ShClyst TuffGvl Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) AK-AM-0901916736 - - POOH w/ cleanout BHA - Date: Avg to9089' 29.0 washed/reamed down T/9,079' MD. Took spot samples ~10 mins, saw <15% cement with Phenolphthalein . Attempted to rotate - 11000' 11000' 0' Max @ ft Current Minimum Depth Time: - in -- Gas Summary - -- C-5n - - C-2 - SPP (psi) Gallons/stroke TFABit Type Depth 2.545 N-80 MBT 10918' pH 0.464 - - - Siltst 7.00'' 0 0 Units* Casing Summary Lithology (%) -- - 907-283-1309Unit Phone: - Jane Grundin Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs Set AtSize 29.0 N-80 Grade N-809068' 7.00'' 7.00'' (max)(current) Production - - Cly - 7.0 67 2-2-CT-A-X-1-WT-RIG2HDBS MM 55 PDC 6 0.464 49.13 9109' 10273' . . * 24 hr Recap: 7.0 67 2-2-CT-A-X-1-WT-RIG2HDBS MM 55 PDC 6 0.464 49.13 9109' 10273' (max)(current) Production - - Cly - Set AtSize 29.0 N-80 Grade N-809068' 7.00'' 7.00'' 907-283-1309Unit Phone: - Jane Grundin Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs - - 7.00'' 0 0 Units* Casing Summary Lithology (%) - N-80 MBT 10918' pH 0.464 - - - Siltst SPP (psi) Gallons/stroke TFABit Type Depth 2.543 C-5n - - C-2 - in -- Gas Summary - -- Minimum Depth Time: - dumped 64 bbls water/mud. RIH T/9,075' MD and milled through junk T/9,082' MD. Pumped sweep, then another sweep, then - 11000' 11000' 0' Max @ ft Current - Date: Avg to9089' 29.0 Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) AK-AM-0901916736 - - POOH w/ Milling Assy (current) J. Grubb/ D. Yessak ShClyst TuffGvlCoal cP 13 20' 6 0.464 Footage 17.99 727' 7.76 1164' Sst (ppb Eq) C-1 C-5i Cht C-4i C-4n PV 24 hr Max 26.0 Weight Sd YP (lb/100ft2) 8.80 - Hours C-3 -- Cement --- 74 - HDBS MM 55 PDC KCL 4.5 10273' 11000'19 11000' Depth in / out Mud Type Lst Production Type Average 98611Background (max)Trip N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min Tools Gamma, Res, PWD API FL Chromatograph (ppm) 8 7.09089' 9109' WOB Production 100% Gas In Air=10,000 Units-Connection - 3 Geology: N/A Fluids: 0 bbls Max Gas: N/A decided to POOH. Spotted 13 ppg mud cap, began POOH T/ surface. Checked flow- static. POOH @ 8686' MD at time of report. 6489' 4527' Condition 2-7-BT-G-X-N-PN-PR Bit # 1 10.3 6 10.80 HDBS MM 55 PDC 10.80 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: Morning Report Report # 25 Customer: Well: Area: Location: Rig: SCU 41B-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Field 2-3-BT-G-X-I-CT-TD ROP ROP (ft/hr) 3.09 @ Mud Data Depth 13-Jan-2015 23:59 Current Pump & Flow Data: 0 Max - Chlorides mg/l 30500 Finished POOH T/ surface, service rig, and M/U milling assembly. RIH T/9,002' MD, CBU 9,861U of gas and Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Finished POOH T/surface. L/D BHA, performed rig service, and TIH w/milling assy and bent sub T/9,036' MD. CBU Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 30500 - 14-Jan-2015 23:59 Current Pump & Flow Data: 1596 Max 2-3-BT-G-X-I-CT-TD ROP ROP (ft/hr) 3.09 @ Mud Data Depth Morning Report Report # 26 Customer: Well: Area: Location: Rig: SCU 41B-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: Condition 2-7-BT-G-X-N-PN-PR Bit # 1 10.3 6 10.80 HDBS MM 55 PDC 10.80 Size 3 Geology: N/A Fluids: 0 bbls Max Gas: N/A T/9,099' MD and pumped sweep. Milling ahead @ 9,101' MD at time of report. 6489' 4527' 100% Gas In Air=10,000 Units-Connection - Tools Gamma, Res, PWD API FL Chromatograph (ppm) 8 7.09089' 9109' WOB Production N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min 7Background (max)Trip Average 9872 Mud Type Lst Production Type 74 - HDBS MM 55 PDC KCL 5.4 10273' 11000'18 11000' Depth in / out ---- Hours C-3 -- Cement PV 24 hr Max 26.0 Weight Sd YP (lb/100ft2) 9.00 1164' Sst (ppb Eq) C-1 C-5i Cht C-4i C-4n Coal cP 11 20' 6 0.464 Footage 17.99 727' 7.76 (current) J. Grubb/ D. Yessak ShClyst TuffGvl Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) AK-AM-0901916736 - - Milling Open Hole - Date: Avg to9089' 29.0 9,872U of gas and dumped 63 bbls water/mud. Washed/reamed T/9,079' MD, pumped sweep, and checked flow- 0.9 bph. Milled - 11000' 11000' 0' Max @ ft Current Minimum Depth Time: - in -- Gas Summary - -- C-5n - 6.6 C-2 - SPP (psi) Gallons/stroke TFABit Type Depth 2.543 N-80 MBT 10918' pH 0.464 - - - Siltst 7.00'' 256 87 Units* Casing Summary Lithology (%) -- - 907-283-1309Unit Phone: - Jane Grundin Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs Set AtSize 29.0 N-80 Grade N-809068' 7.00'' 7.00'' (max)(current) Production - - Cly - 7.0 67 2-2-CT-A-X-1-WT-RIG2HDBS MM 55 PDC 6 0.464 49.13 9109' 10273' . . * 24 hr Recap: 7.0 67 2-2-CT-A-X-1-WT-RIG2HDBS MM 55 PDC 6 0.464 49.13 9109' 10273' (max)(current) Production - - Cly - Set AtSize 29.0 N-80 Grade N-809068' 7.00'' 7.00'' 907-283-1309Unit Phone: - Jane Grundin Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs - - 7.00'' 0 0 Units* Casing Summary Lithology (%) - N-80 MBT 10918' pH 0.464 - - - Siltst SPP (psi) Gallons/stroke TFABit Type Depth 2.546 C-5n - - C-2 - in -- Gas Summary - -- Minimum Depth Time: - of window and checked flow- static. Pumped 13 ppg mud cap. Continued POOH T/ surface to test BOP. Checked flow- 0.5 bph. - 11000' 11000' 0' Max @ ft Current - Date: Avg to9089' 29.0 Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) AK-AM-0901916736 - - Testing BOP (current) J. Grubb/ D. Yessak ShClyst TuffGvlCoal cP 12 20' 6 0.464 Footage 17.99 727' 7.76 1164' Sst (ppb Eq) C-1 C-5i Cht C-4i C-4n PV 24 hr Max 26.0 Weight Sd YP (lb/100ft2) 9.20 - Hours C-3 -- Cement --- 74 - HDBS MM 55 PDC KCL 5.1 10273' 11000'19 11000' Depth in / out Mud Type Lst Production Type Average 1070Background (max)Trip N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min Tools Gamma, Res, PWD API FL Chromatograph (ppm) 8 7.09089' 9109' WOB Production 100% Gas In Air=10,000 Units-Connection - 3 Geology: N/A Fluids: 0 bbls Max Gas: N/A Testing BOP at time of report. 6489' 4527' Condition 2-7-BT-G-X-N-PN-PR Bit # 1 10.3 6 10.80 HDBS MM 55 PDC 10.80 Size Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: Morning Report Report # 27 Customer: Well: Area: Location: Rig: SCU 41B-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Field 2-3-BT-G-X-I-CT-TD ROP ROP (ft/hr) 3.09 @ Mud Data Depth 15-Jan-2015 23:59 Current Pump & Flow Data: 0 Max - Chlorides mg/l 30000 Continue milling F/9,101' MD T/9,177' MD, pumping sweeps @ 9,113' MD, 9,122' MD, and 9,177' MD. POOH T/ top Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: 727'8 74 2-3-BT-G-X-I-CT-TD3HDBS MM 55 PDC 6 0.464 17.99 10273' 11000' Completed and passed BOP testing. R/D test equipment and pulled test plug. Slip/cut drill line and serviced rig. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 30000 - 16-Jan-2015 23:59 Current Pump & Flow Data: 0 Max ROP ROP (ft/hr) 3.09 @ Mud Data Depth Morning Report Report # 28 Customer: Well: Area: Location: Rig: SCU 41B-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: ConditionBit # 10.310.8010.80 Size 5 Geology: N/A Fluids: 0 bbls Max Gas: N/A Begin RIH, RIH @ 9,050' MD at time of report. 6489' 4527' 100% Gas In Air=10,000 Units-Connection - Tools Gamma, Res, PWD API FL Chromatograph (ppm) WOB Production N/AN/A Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max)Trip Average 224 Mud Type Lst Production Type HDBS FX64 PDC KCL 5.0 11000' 11000'19 Depth in / out ---- Hours C-3 -- Cement PV 24 hr Max 26.0 Weight Sd YP (lb/100ft2) 8.60 1164' Sst (ppb Eq) C-1 C-5i Cht C-4i C-4n Coal cP 12 6 0.460 Footage (current) J. Grubb/ D. Yessak ShClyst TuffGvl Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) AK-AM-0901916736 - - RIH w/ Directional - Date: Avg to9089' 29.0 M/U directional BHA and test- MWD tools failed. Changed collars and retested- passed. Re-install wear bushing, and P/U HWDP. - 11000' 11000' 0' Max @ ft Current Minimum Depth Time: - in -- Gas Summary - -- C-5n - - C-2 - SPP (psi) Gallons/stroke TFABit Type Depth 2.546 N-80 MBT 10918' pH - - - Siltst 7.00'' 0 0 Units* Casing Summary Lithology (%) -- - 907-283-1309Unit Phone: - Jane Grundin Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs Set AtSize 29.0 N-80 Grade N-809068' 7.00'' 7.00'' (max)(current) Production - - Cly - 7.0 67 2-2-CT-A-X-1-WT-RIG2HDBS MM 55 PDC 6 0.464 49.13 9109' 10273' . . * 24 hr Recap: 67 2-2-CT-A-X-1-WT-RIG2HDBS MM 55 PDC 6 0.464 49.13 9109' 10273' 0 Cly 1052 Size 29.0 N-80 Grade N-809068' 7.00'' 7.00'' Production 907-283-1309Unit Phone: 0 Jane Grundin Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs 952 670 7.00'' 238 81 Units* Casing Summary Lithology (%) 0 10918' pH 0 0 0 Siltst Set At 0 SPP (psi) Gallons/stroke TFABit Type Depth 2.542 MBT 9211' 2.9 C-2 27 in 7 9216' Gas Summary 0 0 0 C-5n Minimum Depth Time: 9211' F/9,050' MD T/9,127' MD, wash/ream T/9,177' MD. P/U Gryo, RIH w/Wireline, take surveys F/9,120' MD T/9,070' MD. POOH 14 - 9215' - Max @ ft Current 1.9 Date: Avg to9089' 29.0 Yesterday's Depth: Current Depth: 24 Hour Progress: 25.2 Flow In (gpm) Flow In (spm) AK-AM-0901916736 - - Drilling Ahead (current) J. Grubb/ D. Yessak ShClyst TuffGvl cP 11 6 0.460 Footage Sst (ppb Eq) C-1 C-5i Cht C-4i C-4n Coal PV 24 hr Max 26.0 Weight Sd YP (lb/100ft2) 9.00 Hours C-3 00 Cement 1164' 19 Depth in / out 0000 Mud Type Lst Production Type Average 5690 (max)Trip (max)(current) Comments RPM ECD (ppg) ml/30min 5.8 N-80 7.0 Tools Gamma, Res, PWD API FL Chromatograph (ppm) WOB Production w/Wireline , L/D Gyro. Drilled T/9,207' MD and CBU. P/U Gyro and RIH w/Wireline, took surveys. Decided to drill ahead, drilling 6489' 4527' 100% Gas In Air=10,000 Units-Connection 0 Geology: N/A Fluids: 0 bbls Max Gas: 27 ahead w/Gyro @ 9,215' MD at time of report. Bit # 10.210.8010.80 Size 5 HDBS FX64 PDC KCL 11000' 11000' Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: Morning Report Report # 29 Customer: Well: Area: Location: Rig: SCU 41B-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Field ROP ROP (ft/hr) 3.09 @ Mud Data Depth Condition 17-Jan-2015 23:59 Current Pump & Flow Data: 2417 Max N/AN/A Avg Min 2Background 0 % Chlorides mg/l 30000 11000' R/U Wireline and RIH T/9,050' MD, through window. CBU 5,690U of gas. POOH w/Wireline and L/D Gyro. TIH Density (ppg) out (sec/qt) Viscosity Cor Solids 727'8 74 2-3-BT-G-X-I-CT-TD3HDBS MM 55 PDC 6 0.464 17.99 10273' . . * 24 hr Recap: 3 HDBS MM 55 PDC 6 0.464 17.99 10273' Drill ahead w/Gyro F/9,215' MD T/9,230' MD. Serviced rig, and drill ahead F/9,230' MD T/9,242' MD. POOH Density (ppg) out (sec/qt) Viscosity Cor Solids 727' mg/l 30500 11000' 8 74 6 5Background N/AN/A Avg Min % Chlorides 2-3-BT-G-X-I-CT-TD Depth Condition 18-Jan-2015 23:59 Current Pump & Flow Data: 1843 Max ROP ROP (ft/hr) 3.09 @ Mud Data Morning Report Report # 30 Customer: Well: Area: Location: Rig: SCU 41B-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: Bit # 10.510.8010.80 Size 5 HDBS FX64 PDC KCL 11000' 9261' Geology: 100% Siltstone: med bn-gry, frm, blky, homog, non calc, sl tf, r Sst; NSOFC Fluids: 0 bbls Max Gas: 4,045U Gyro, R/D. Checked flow- 7 bph, CBU 4,045U of gas. pumped sweep. Drilling ahead @ 9,277' MD at time of report. 6489' 4527' 100% Gas In Air=10,000 Units-Connection 18 Tools Gamma, Res, PWD API FL Chromatograph (ppm) WOB Production RPM ECD (ppg) ml/30min 4.8 7.0 (max)Trip (max)(current) Average - Mud Type Lst Production Type Depth in / out 00011 Comments C-3 00 Cement PV 24 hr Max 26.0 Weight Sd YP (lb/100ft2) 9.40 Sst (ppb Eq) C-1 C-5i Cht C-4i C-4n Coal Hours cP 12 6 0.460 Footage 1164' 18 (current) J. Grubb/ D. Yessak ShClyst TuffGvl Yesterday's Depth: Current Depth: 24 Hour Progress: 78.6 Flow In (gpm) Flow In (spm) AK-AM-0901916736 - - Drilling 6" Production Hole 2.2 Date: Avg to9089' 29.0 w/Wireline and Gyro for connection, then RIH w/Wireline and Gyro. Continue drilling ahead T/9,250' MD. POOH w/Wireline and 34 9215' 9277' 62' Max @ ft Current Minimum Depth Time: 9274' in 6 9231' Gas Summary 0 0 0 C-5n 9252' 2.6 C-2 4,045 SPP (psi) Gallons/stroke TFABit Type Depth 2.548 MBT 10918' pH 0 1 0 Siltst Set At 76 7.00'' 229 78 Units* Casing Summary Lithology (%) 0 100 4575 811 907-283-1309Unit Phone: 0 Jane Grundin Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs Size 29.0 N-80 Grade N-809068' 7.00'' 7.00'' Production N-80 0 Cly 79478 67 2-2-CT-A-X-1-WT-RIG2HDBS MM 55 PDC 6 0.464 49.13 9109' 10273' . . * 24 hr Recap: 9109' 10273' 17560 67 2-2-CT-A-X-1-WT-RIG2HDBS MM 55 PDC 6 0.464 49.13 29.0 N-80 Grade N-809068' 7.00'' 7.00'' Production N-80 907-283-1309Unit Phone: 0 Jane Grundin Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs 2571 577 7.00'' 245 83 Units* Casing Summary Lithology (%) 0 0 0 0 Siltst 45 1 SPP (psi) Gallons/stroke TFABit Type Depth 2.545 MBT C-2 140 N/A Set AtSize Cly 6 9305' Gas Summary 0 0 0 C-5n Minimum Depth Time: 9315' CBU 5,742U, check flow-9 bph, contiuned drilling ahead. Drilling ahead @ 9,424' MD at time of report. 29 9277' 9424' 147' Max @ ft Current Avg toN/A 29.0 in 9314' 11.9 Yesterday's Depth: Current Depth: 24 Hour Progress: 112.3 Flow In (gpm) Flow In (spm) AK-AM-0901916736 - - Drilling 6" Production Hole (current) J. Grubb/ D. Yessak ShClyst TuffGvl cP 13 6 0.460 Footage 1164' 18 Sst (ppb Eq) C-1 C-5i Cht C-4i C-4n Coal Hours PV 24 hr Max 26.0 Weight Sd YP (lb/100ft2) 9.30 C-3 00 Cement Depth in / out 0006 Comments Mud Type Lst 100 Production Type Average 5742 (max)Trip (max)(current) RPM ECD (ppg) ml/30min 4.0 7.0 pH Tools - API FL Chromatograph (ppm) WOB Production 6489' 4527' 100% Gas In Air=10,000 Units397Connection 20 Geology: 100% Sandstone : wh, sft, f-crs gr, r v crs clr qtz gr, sb-rnd, mod-pr srt, pr cons, Tf cem, com Sd, tr Sltst, r C; NSOFC. Fluids: 0 bbls Max Gas: 140U Bit # 10.410.8010.80 Size 5 HDBS FX64 PDC KCL 11000' 9394' MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: 5.9 Date: SCU 41B-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Field Job No.: Daily Charges: Total Charges: 3.09 @ Mud Data Morning Report Report # 31 Customer: Well: Area: Location: Rig: Depth Condition 19-Jan-2015 23:59 Current Pump & Flow Data: 2345 Max ROP ROP (ft/hr) N/AN/A Avg Min % Chlorides 2-3-BT-G-X-I-CT-TD 6Background 1 mg/l 32000 11000' 8 74 Continued drilling ahead F/ 9,277' MD T/ 9,294' MD, service rig. Drilled F/9,294' MD T/ 9,326' MD and R/D Wireline. Density (ppg) out (sec/qt) Viscosity Cor Solids 727'3 HDBS MM 55 PDC 6 0.464 17.99 10273' . . * 24 hr Recap: 3 HDBS MM 55 PDC 6 0.464 17.99 10273' Drilling ahead @ 9,424' MD, check flow-12 bph, continued drilling T/ 9,445' MD. Pumped sweep and drilled T/ 9,581' Density (ppg) out (sec/qt) Viscosity Cor Solids 727' mg/l 32000 11000' 8 74 8 0Background N/AN/A Avg Min % Chlorides 2-3-BT-G-X-I-CT-TD Depth Condition 20-Jan-2015 23:59 Current Pump & Flow Data: 0 Max ROP ROP (ft/hr) 3.09 @ Mud Data Morning Report Report # 32 Customer: Well: Area: Location: Rig: SCU 41B-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: 6.4 Date: Bit # 10.610.8010.80 Size 5 HDBS FX64 PDC KCL 11000' 9581' Geology: 50% Siltstone : lt gry, sft-fri, amor, sdy, homog, non-calc, occ lt gry Sst, r dk gry-tn Sltst frag; NSOFC. : 40% Sand : lt gry, Fluids: 0 bbls Max Gas: 126U BHA, POOH and L/D BHA at time of report. 6489' 4527' 100% Gas In Air=10,000 Units364Connection 18 RPM ECD (ppg) ml/30min 5.0 7.0 pH Tools - API FL (max)Trip (max)(current) Average 4 Mud Type Lst 10 Production Type Chromatograph (ppm) 17 Comments Production 000 C-3 00 Cement PV 24 hr Max 26.0 Weight Sd YP (lb/100ft2) 9.20 (ppb Eq) C-1 C-5i Cht C-4i C-4n Coal Hours Depth in / out Footage 1164' 18 WOB R. Pederson/ D. Yessak ShClyst TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: 92.2 Flow In (gpm) Flow In (spm) AK-AM-0901916736 - - POOH/ change BHA Avg toN/A 29.0 in 9466' N/A loc bn, clr-transl, Qtz, lith, crs-med, sub-ang, mod srt, com Glauc, com C; 10% Sandstone. MD and CBU 182 U of gas. POOH T/ window, checked flow-10 bph, spotted 13 ppg mud cap. Continued POOH T/ surface for new 21 9424' 9581' 157' Max @ ft Current Minimum Depth Time: 9557' 6 9527' Gas Summary 0 0 0 C-5n 126 N/A Set AtSize Cly (current) 6 0.460 Sst SPP (psi) Gallons/stroke TFABit Type Depth 2.543 MBT 0 0 0 0 Siltst 48 0 7.00'' 0 0 Units* Casing Summary Lithology (%) C-2 12 50 1979 732 Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs 9068' 7.00'' 7.00'' Production N-80 907-283-1309Unit Phone: 0 Ryan Lenberg 2-2-CT-A-X-1-WT-RIG2HDBS MM 55 PDC 6 0.464 49.13 9109' 10273' 14552 40 67 29.0 N-80 Grade N-80 . . * 24 hr Recap: 74 29.0 N-80 Grade N-80 907-283-1309Unit Phone: 0 Ryan Lenberg 2-3-BT-G-X-I-CT-TD3HDBS MM 55 PDC 6 0.464 9068' 7.00'' 7.00'' Production N-80 8098Maximum Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs 3101 1777 7.00'' 242 83 Units* Casing Summary Lithology (%) C-2 13 0 0 Siltst 23 0 40 TFABit Type Depth 2.547 MBT 0 0 C-5n 59 9606' Set AtSize Cly 9606' MD 4 9620' Gas Summary 9581' 9657' 76' Max @ ft Current Minimum Depth Time: in 9632' 41.5 40% Siltstone : dk bn, blk, r tn, v hrd, ang, occ lam, homog. 7021' MD, CBU 9,137U of gas, and dumped 98 bbls of water/mud. Flow check-20 bph, continued RIH T/ 9,040' P/U Gyro and RIH 21 - Drilling 6' production hole Avg to9582' 29.0 (current) 6 0.451 TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0901916736 - R. Pederson/ D. Yessak ShClyst 71.3 Sst SPP (psi) Gallons/stroke Footage 727' 18 WOB 17.99 10273' 11000' (ppb Eq) C-1 C-5i Cht C-4i C-4n Coal Hours Depth in / out PV 24 hr Max 26.0 Weight Sd YP (lb/100ft2) 9.90 C-3 00 Cement 000 0 0 0 9 Comments Production Mud Type Lst 60 Production Type Chromatograph (ppm) Average 9137 (max)Trip (max)(current) RPM ECD (ppg) ml/30min 5.2 8 pH Tools Gamma and Resistivity API FL on wire line, orientated tools, and exited window. Flow check-22 bph, RIH T/ 9,276' MD, CBU 7,744U of gas and dumped 231 6489' 4527' 100% Gas In Air=10,000 Units65Connection 9 Geology: 60% Sandstone: lt gry-gry, wh, sft, heterog, Qtz gr, v f gr, sub-rnd, p-mod srt, com tf cmnt, slty ip, r C frags; NSOFC. Fluids: 0 bbls Max Gas: 59U bbls of water/mud. Drilled ahead T/ 9,638' MD, flow check-1.5 bph. Drilling ahead @ 9,657' MD at time of report. Bit # 10.510.8010.80 Size 6 Smith MDi513 PDC KCL 9582' 9606' MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: 3.0 Date: SCU 41B-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Field Job No.: Daily Charges: Total Charges: 3.09 @ Mud Data Morning Report Report # 33 Customer: Well: Area: Location: Rig: Depth Condition 21-Jan-2015 23:59 Current Pump & Flow Data: 2083-2094 Max ROP ROP (ft/hr) N/AN/A Avg Min % Chlorides 2-3-CT-A-X-1-JD-PR 7Background 0 mg/l 30500 9581'9 56 Flow check -8 bph and finished L/D BHA. M/U new BHA and began RIH. Flow check-8.5 bph, continued RIH T/ Density (ppg) out (sec/qt) Viscosity Cor Solids 526'5 HDBS FX64 PDC 6 0.460 77.47 9055' . . * 24 hr Recap: 5 HDBS FX64 PDC 6 0.460 77.47 9055' Continued drilling F/9,657' MD T/9,700' MD, checked flow- 1 bph. Drilled T/9,763' MD, checked flow- 3.5 bph. Density (ppg) out (sec/qt) Viscosity Cor Solids 526' mg/l 31000 9581'9 56 152 5Background N/AN/A Avg Min % Chlorides 2-3-CT-A-X-1-JD-PR Depth Condition 22-Jan-2015 23:59 Current Pump & Flow Data: 2194 Max ROP ROP (ft/hr) 3.09 @ Mud Data Morning Report Report # 34 Customer: Well: Area: Location: Rig: SCU 41B-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: 56.3 Date: Bit # 10.610.8510.85 Size 6 Smith MDi513 PDC KCL 9582' 11003' Geology: (9930' MD) 90% Sand : clr-transl, wh, lt gry-gry, Qtz, lith, sb-rnd, v f-f gr, w srt; NSOFC ; 10% Siltstone. Fluids: 0 bbls Max Gas: 9941U POOH @ 10,833' MD at time of report. washed and reamed T/bottom, confirmed on bottom by DD. Pumped sweep, CBU minimal gas and began POOH w/ Madpass. T/10,260' MD. Decided to POOH T/point of intersection to rework, checked flow- 8.5 bph. After reworking, TIH T/ 10,260' MD, 6489' 4527' 100% Gas In Air=10,000 Units7979Connection 383 RPM ECD (ppg) ml/30min 4.2 8 pH Tools Gamma and Resistivity API FL (max)Trip (max)(current) Average 5610 Mud Type Lst Production Type Chromatograph (ppm) Comments Production 0 15 35 538 0230 9.80 C-3 07 Cement Depth in / out PV 24 hr Max 26.0 Weight Sd YP (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage 727' 19 WOB 17.99 10273' 11000' R. Pederson/ D. Yessak ShClyst 4284.0 Sst SPP (psi) Gallons/stroke TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0901916736 - - POOH / Madpass Avg to9582' 29.0 (current) 6 0.451 in 9929' 0.0 Pumped sweep and drilled ahead T/9,908' MD. Entered previous well bore and worked intersection, washed and reamed 496 9657' 11003' 1346' Max @ ft Current Minimum Depth Time: 10153' 3 11009' Gas Summary 10 0 C-5n 9941 9606' Set AtSize Cly TFABit Type Depth 2.553 MBT (ppb Eq) Hours 17 42 4 Siltst 1315 83 7.00'' 242 83 Units* Casing Summary Lithology (%) C-2 Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs 70938 N-80 696975 90 Maximum 9788 10 2-3-BT-G-X-I-CT-TD3HDBS MM 55 PDC 6 0.464 9068' 7.00'' 7.00'' Production 74 29.0 N-80 Grade N-80 907-283-1309Unit Phone: 0 Jane Grundin . . * 24 hr Recap: 74 29.0 N-80 Grade N-80 907-283-1309Unit Phone: - Jane Grundin 2-3-BT-G-X-I-CT-TD3HDBS MM 55 PDC 6 0.464 9068' 7.00'' 7.00'' Production N-80 -Maximum - Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs - 7.00'' 0 0 Units* Casing Summary Lithology (%) C-2 - - Siltst - - TFABit Type Depth 2.548 MBT (ppb Eq) Hours -- C-5n N/A 11003' Set AtSize Cly - N/A - Gas Summary 11003' 11003' 0' Max @ ft Current Minimum Depth Time: in - - sweep, spotted pill, and POOH T/8,996' MD. Checked flow- 1.5 bph and spotted 13 ppg mud cap, POOH T/3,250' MD. Began N/A - POOH L/D DP Avg to9582' 29.0 (current) 6 0.451 TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0901916736 - R. Pederson/ D. Yessak ShClyst - Sst SPP (psi) Gallons/stroke 727' 19 WOB 17.99 10273' 11000' 14 (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage Depth in / out PV 24 hr Max 26.0 Weight Sd YP - 8.70 C-3 -- Cement - - - --- Comments Production Mud Type Lst Production Type Chromatograph (ppm) Average 9575 (max)Trip (max)(current) RPM ECD (ppg) ml/30min 4.6 8 pH Tools Gamma and Resistivity API FL L/D singles and continued POOH T/surface. L/D BHA and downloaded tools, L/D BHA at time of report. 6489' 4527' 100% Gas In Air=10,000 UnitsN/AConnection - Geology: N/A Fluids: 0 bbls Max Gas: N/A Bit # 10.810.8010.80 Size 6 Smith MDi513 PDC KCL 9582' 11003' MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: - Date: SCU 41B-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Field Job No.: Daily Charges: Total Charges: 3.09 @ Mud Data Morning Report Report # 35 Customer: Well: Area: Location: Rig: Depth Condition 23-Jan-2015 23:59 Current Pump & Flow Data: 0 Max ROP ROP (ft/hr) N/AN/A Avg Min % Chlorides 2-3-CT-A-X-1-JD-PR 0Background - mg/l 29000 9581'9 56 Continued POOH F/10,833' MD T/10,627' MD. Checked flow- 2.5 bph. POOH T/9,110' MD, RIH T/bottom, pumped Density (ppg) out (sec/qt) Viscosity Cor Solids 526'5 HDBS FX64 PDC 6 0.460 77.47 9055' . . * 24 hr Recap: 5 HDBS FX64 PDC 6 0.460 77.47 9055' Finished L/D Dp and BHA, checked flow- 4.3 bph. R/U Weatherford and began RIH w/4.5" liner. P/U liner hanger Density (ppg) out (sec/qt) Viscosity Cor Solids 526' mg/l 29000 9581'9 56 - 509Background 1-2-CT-A-X-I-JD-TD N/AN/A Avg Min % Chlorides 2-3-CT-A-X-1-JD-PR Depth Condition 24-Jan-2015 23:59 Current Pump & Flow Data: 809 Max ROP ROP (ft/hr) 3.09 @ Mud Data Morning Report Report # 36 Customer: Well: Area: Location: Rig: SCU 41B-04 Hilcorp Alaska LLC Kenai Peninsula Swanson River Field Job No.: Daily Charges: Total Charges: MWD Summary 95% Rig Activity: N/A Saxon 169 Report For: - Date: Bit # 10.610.8010.80 Size 6 Smith MDi513 PDC KCL 9581' 11003' Geology: N/A Fluids: 0 bbls Max Gas: N/A once on bottom with 8,046U max gas and dumping 112 bbls water/mud. Circulating and conditioning mud at time of report. 6.5 bph. RIH through window w/o issue, continued RIH w/ tight spot @ 9,910' MD. Washed down last 2 stands and circulated S/S 6489' 4527' 100% Gas In Air=10,000 UnitsN/AConnection - RPM ECD (ppg) ml/30min 60 4.8 8 pH Tools Gamma and Resistivity API FL (max)Trip (max)(current) Average 9810 Mud Type Lst Production Type Chromatograph (ppm) 10 Comments Production - - - ---- 9.40 C-3 -- Cement Depth in / out PV 24 hr Max 26.0 Weight Sd YP (lb/100ft2) C-1 C-5i Cht C-4i C-4n Coal Footage 33.77 327' 727' 17 9908' WOB 17.99 10273' 11000' 12 R. Pederson/ D. Yessak ShClyst - Sst SPP (psi) Gallons/stroke TuffGvl cP Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) AK-AM-0901916736 - - Circulating Avg to9582' 29.0 (current) 6 0.451 in - - and switch to DP. RIH T/8,990' MD and circulated S/S with max gas of 9,810U and dumping 44 bbls water/mud. Checked flow- N/A 11003' 11003' 0' Max @ ft Current Minimum Depth Time: - N/A - Gas Summary -- C-5n N/A 11003' Set AtSize Cly TFABit Type Depth 2.548 MBT (ppb Eq) Hours - - Siltst - - 7.00'' 176 57 Units* Casing Summary Lithology (%) C-2 Report By:Logging Engineers:Jane Grundin / Jeremy Tiegs - N-80 -Maximum - 2-3-BT-G-X-I-CT-TD3HDBS MM 55 PDC 6 0.464 9068' 7.00'' 7.00'' Production 74 29.0 N-80 Grade N-80 907-283-1309Unit Phone: - Jane Grundin
