Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
214-112
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Ryan Lemay Cc:Donna Ambruz; Roby, David S (OGC) Subject:RE: BCU - 24 / PTD 214-112 / Sundry # 325-497 / PLT - Commingled Tyonek & Beluga Date:Wednesday, October 15, 2025 12:27:00 PM Attachments:Hilcorp Alaska_Beaver Creek Unit 24_5013320639_20250926_PL Analysis Report (1).pdf BCU-24 AOGCC 10-403 325-497 PTD 214-112 Approved 09-02-25.pdf Ryan, Hilcorp’s request is approved. The log run 9/26/25 is acceptable to fulfil the obligations of CO 237D Rule 5a. Submit electronic copies of the logs and allocation of production within 30 days of completion of logging operations. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Ryan Lemay <ryan.lemay@hilcorp.com> Sent: Wednesday, October 15, 2025 11:17 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: BCU - 24 / PTD 214-112 / Sundry # 325-497 / PLT - Commingled Tyonek & Beluga Good morning Bryan, This is a follow up to our conversation on Friday 10/10/25. From 9/16-9/18/25, we perforated the below intervals per the approved Sundry (attached for reference). Prior to perforations being added the well was producing approximately 0-5 bwpd on periodic soap cycles. Post perforations water production increased to 50-60 bbls water per day. A PLT was run on the well 9/26 to get updated gas and water rate results to satisfy step 4 of the procedure and CO 237D Rule 5(c) due to Tyonek and Beluga pools being commingled on this well. PLT analysis results are attached to this e-mail for reference. When we were executing operations we had seen a rate decrease and an increase in water production after shoot the Bel 19 zone 8005’-8011’. After running the PLT, we decided to set a patch from 8001.5’ – 8013’ on 10/3 in hopes it may shut off some water production and or increase gas rate. However, this proved not to be the case. After setting the patch across the Bel 19 zone, gas and water rate remained the same as when the PLT was run on 9/26. Hilcorp Request for Approval: Even though further well work operations (setting patch) was completed after the PLT on 9/26, the gas and water rate remained the same pre and post patch setting operations. Hilcorp is requesting the PLT analysis run on 9/26 satisfies and provides the necessary data for commingling requirements CO 237D Rule 5(c). PLT analysis shows ~1.9% of production coming from the Tyonek intervals and 98.1% from the Beluga intervals in the well. Well Sand Top MD Btm MD Top TVD Btm TVD Interval BCU-24 BEL 16 +7,708’+7,718’±7,106'±7,116'±10'Perfed BCU-24 BEL 16L +7,793’+7,805’±7,191'±7,203'±12'Perfed BCU-24 BEL 18 +7,920’+7,930’±7,318'±7,327'±10'Perfed BCU-24 BEL 18 +7,931’+7,938’±7,328'±7335'±7'Perfed BCU-24 BEL 19 +7,950’+7,955’±7,347'±7,352'±5'Perfed BCU-24 BEL 19 +7,987’+7,992’±7,384'±7,389'±5'Perfed BCU-24 BEL 19 +8,005’+8,011’±7,402'±7,408'±6'Perfed BCU-24 BEL 19 +8,015’+8,018’±7,412'±7,415'±3'Perfed BCU-24 BEL 20 +8,034’+8,049’±7,431'±7,446'±15'Perfed BCU-24 BEL 20 +8,054’+8,058’±7,451'±7,455'±4'Perfed BCU-24 BEL 20 +8,061’+8,071’±7,458'±7,468'±10'Perfed BCU-24 BEL 21 +8,210’+8,215’±7,607'±7,612'±5'Perfed BCU-24 BEL 22 +8,235’+8,253’±7,631'±7,649'±18'Perfed BCU-24 BEL 22 +8,262’+8,272’±7,658'±7,668'±10'Perfed BCU-24 BEL 22 +8,273’+8,288’±7,669'±7,684'±15'Perfed BCU-24 BEL 25 +8,417’+8,423’±7,813'±7,819'±6' Skipped – unable to get guns by restriction BCU-24 BEL 27 +8,524’+8,535’±7,920'±7,931'±11' Skipped – unable to get guns by restriction BCU-24 BEL 29L +8,833’+8,842’±8,229'±8,238'±9' Skipped – unable to get guns by restriction BCU-24 BEL 29L +8,845’+8,853’±8,241'±8,249'±8' Skipped – unable to get guns by restriction BCU-24 BEL 29L +8,857’+8,862’±8,253'±8,258'±5' Skipped – unable to get guns by restriction BCU-24 T1X +9,176’+9,182’±8,572'±8,578'±6' Skipped – unable to get guns by restriction BCU-24 T1X +9,207’+9,210’±8,603'±8,606'±3' Skipped – unable to get guns by restriction BCU-24 T1X +9,215’+9,221’±8,611'±8,617'±6' Skipped – unable to get guns by restriction BCU-24 T1X +9,309’+9,315’±8,705'±8,711'±6' Skipped – unable to get guns by restriction BCU-24 T1 +9,350’+9,354’±8,746'±8,750'±4' Skipped – unable to get guns by restriction Thanks, Ryan LeMay Operations Engineer Swanson River / Beaver Creek Cell: (661) 487-0871 E-mail: Ryan.lemay@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or ifyou have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notifyus by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and anyattachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU J-10B Tubing Swap Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 215-112 50-029-20444-02-00 11462 Conductor Surface Scab Liner Liner Liner 8902 2652 8787 580 668 3189 11204 13-3/8" 9-5/8" 7" x 4-1/2" 7" 3-1/2" x 3-1/4" x 2-7/8" 9033 30 - 2682 27 - 8814 7736 - 8316 8286 - 8954 8273 - 11462 30 - 2682 27 - 8315 7267 - 7829 8285 - 8927 8272 - 9054 None 2670 4760 5410 7020 10530 None 5380 6870 7240 8160 10160 9904 - 11290 4-1/2" 12.6 13cr80 25 - 8170 9051 - 9047 Structural 80 20" 30 - 110 30 - 110 4-1/2" HES TNT Packer 7692 7224 Torin Roschinger Operations Manager Brenden Swensen brenden.swensen@hilcorp.com 907.748.8581 PRUDHOE BAY, Prudhoe Oil Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028281 25 - 7687 N/A N/A 234 348 11260 4927 123 2126 200 1150 880 240 325-312 13b. Pools active after work:Prudhoe Oil No SSSV Installed 7692, 7224 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 2:13 pm, Jul 25, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.07.25 11:53:38 - 08'00' Torin Roschinger (4662) DSR-9/10/25 RBDMS JSB 073125 JJL 8/12/25 ACTIVITY DATE SUMMARY 6/12/2025 ***WELL S/I ON ARRIVAL*** RAN 4.30" CENT TO COLLAPSED TBG AT 7,766' SLM (7797 MD) ***WELL LEFT S/I ON DEPARTURE*** 6/12/2025 ***WELL S/I ON ARRIVAL WSR*** SET JUNK CATCHER ON 4-1/2" PX PLUG AT 8,254' MD (oal= 9'6") ***WELL LEFT S/I ON DEPARTURE*** 6/14/2025 *** WELL S/I ON ARRIVAL*** ( TUBING PUNCH/MECHANICAL TUBING CUT ) RIG UP YJ ELINE. STAB ON TEST PCE 300L/3000H FUNCTION TEST WIRELINE VALVES RIH WITH GAMMA GUN AND 10' ZERO DEGREE PHASE TUBING CIRCULATION GUN GAMMA RAY CORRELATED TO HES MEMORY RADIAL BOND LOG DATED 15- APRIL-2025 TUBING PUNCH INTERVAL 7765' - 7775' CCL TO TOP SHOT = 15.5' CCL STOP = 7749.5 MD SHOTS FIRED, POOH AND RIG IN LRS TO PUMP CONFIRMING CIRCULATION RIH W/ WELLTEC MECHANICAL CUTTER CUTS 7780' FAILED 7770' FAILED 7740' FAILED *** JOB WILL CONTINUE 06/15/2025 *** ***WELL S/I ON DEPARTURE**** 6/14/2025 T/I/O= 130/34/133. LRS 72 Assist E/L (RWO EXPENSE). Verify TBG Punch with 11 bbls of diesel. ***job continued to 06-15-25*** 6/15/2025 ***job continued from 06-14-25***Circ out well down tbg and up IA to J-19 with 200 bbls 1% 110* kcl and 102 bbls 110* 1%kcl with deep clean, let soak for 30 min. Pump remaining 910 bbls 1% KCL, and 134 bbls DSL down tbg up IA. U-tube for 1 hr. Final WHP's 298/285/210. 6/15/2025 *** JOB CONTINUING FROM 6/14/2025 *** *** WELL S/I ON ARRIVAL*** ( MECHANICAL TUBING CUT ) RIG UP YJ ELINE. PRESSURE TEST PCE 300L 3000 HIGH, FUNCTION TEST WIRELINE VALVES RIH W/ WELLTEC MECHANICAL CUTTER CORRELATED TO HES MEMORY RADIAL BOND LOG DATED 15-APRIL-2025 ATTEMPTED CUT AT 7738' FAILED, TRIED TO CUT AND STALLED OUT 24 TIMES *** JOB NOT COMPLETED *** ***WELL S/I ON DEPARTURE**** 6/16/2025 T/I/O = SSV/70/140. Temp = SI. Bleed OAP (pre RWO). No AL. Wellhouse & flowline disconnected. OA FL near surface. Bled Slowly OAP to BT to 0 psi in 10 min. No monitor. E-line in control of valves upon departure. 16:00 Daily Report of Well Operations PBU J-10B Daily Report of Well Operations PBU J-10B 6/16/2025 ***WELL SI ON ARRIVAL*** (WELLTEC CUTTER) MIRU AK ELINE FUNCTION TEST WLVS. PT 250/2500PSI LOG CORRELATED TO HALLIBURTON MEMORY RBL DATED 15-APR-2025 MECHANICAL CUT DEPTH: 7736' CCL-CUT: 23.7' CCL STOP: 7712.3' FINAL MEASUREMENT: 7.021" WELL LEFT SI ON DEPARTURE. RDMO ***JOB COMPLETE*** FINISH RIG DOWN ON 17-JUNE-2025 @0145 6/17/2025 T/I/O = 0/0/40. Set 6" J plug #424 TWC @140". Removed upper tree. Installed bonnet to MV. Torqued to 900 ftlbs. PT'd against MV 350/5000PSI. (PASS). 6/19/2025 T/I/O = TWC/0/0 RWO Remove Tree-THA Bleed test void, control, and balance lines to 0 psi. Rig crew had tree bled to 0 psi, remove tree cap to install lift cap, noticed TWCV was leaking, called out well support to lubricate out 6" J TWCV. Standby 6/19/2025 MIRU, Raise derrirck, found TWC leaking, call out well services to pull TWC 6/20/2025 R/U lubricator and pull TWC, rock out diesel, Install TWC and N/D tree, N/U BOPs 6/20/2025 T/I/O=0/0/40. Pre CTD.TWC Retrieval and Swap. Rigged up lubricator to tree bonnet. Pulled 6" J plug #424 TWC. Removed plug #424 TWC from lubricator and attached #410 TWC. Set 6" J plug #410 TWC. RDMO 6/20/2025 T/I/O = TWC/0/0 RWO Remove Tree-THA Well support pulled leaking 6" J TWCV #424 with lubricator (11 psi tbg), bleed tbg to 0 psi, set TWCV #410 with lubricator and test to 3500 psi, TWCV still leaking, bleed psi to 0, WS pull TWCV #410, RDMO lubricator, standby for rig to circulate out diesel. T/I/O = 0/0/0. Set 6" TWCV #410 with dry rod. Verify 0 psi on test void, ctrl, and balance lines. Attempt to remove DH tree and THA using slings while working wedges and flange spreaders, no success. Have rig hands wrap tree and THA and apply steam, head to TSB, return with FMC tree cap with 7" LTC internal lift thread and 7" LTC pin x 4-1/2" IF box x/o #443, swap out tree caps, remove steam, verify 0 psi on test void and ctrl and balance lines. MU x/o to a joint of 5" DP, MU to internal lift threads of tree cap, MU top drive, work up to 50K over block wt with no success. Pressure up on top of TWCV while working up to 50K pull to get THA free, bleed psi, BO top drive, DP, and x/o, remove DH tree and THA. Clean void, ring groove, hanger neck, check 7" IJ4S lift threads with x/o, 7 RH turns snug, BO x/o, plug 1/4" NPT ctrl line ports (x2) in hanger neck, LDS OUT 3-1/2" to clear bowl, RKB to LDS 24.86', top of hanger neck is 11-3/4" above flange. Pack J stick around top of hanger and OD of TWCV, install new BX-160, standby for rig to NU and test BOPs. Daily Report of Well Operations PBU J-10B 6/21/2025 Function test BOP and flood lines, attempt to shell test but leaking past TWC. RIH and set a Retrievable Bridge plug below the Tbg Hgr at 60'. Attempt to test Blind Rams and could not achieve a low test below 400 psi. We did achieve High Pressure test to 3500psi. Pull and inspect Plug. Set a new Bridge plug with the same results, no low test but achieved high, with flow out the IA on low test.While trouble shooting, we performed a rolling test on the Blind Rams with the Mud Pump Limiter set at 250 psi and charted with continual flow out the IA. Switched to test pump and achieved 3500 psi on chart.Submit Request to the AOGCC to perform the BOP test by utilizing the Rolling low test with the mud pump and High test with the test pump. Recieved confirmation to perform Rolling BOP Test from AOGCC Jack Lau. Test BOP and associated equipment against 7" pipe size. 250/3500 psi. Test PVT System and gas alarms. 6/21/2025 T/I/O = TWCV/0/0 RWO Decompletion 6" J TWCV still leaking by during BOP test, sting intoTWCV to offseat poppet, 0 psi under plug, pull TWCV #410 with dry rod, standby for rig to set 7" bridge plug and test BOPs 6/22/2025 Cont. testing BOPE :Attempt to test Choke HCR and manual choke valves (failed) regrease same and purge air from chart sensor, test 7" LPR (passed). retest Choke HCR and Manual valves. Test Super Choke and Manual Choke. Perform Accumulator Test: Initial = 3000 psi. After closure = 1650 psi, 200 psi recharge = 28 sec, Full recovery = 69 sec. R/D testing equipment. L/D 7' test Jt. RIH to 60', pull and L/D Bridge plug. Pull Tbg Hgr to floor. POOH L/D 7" Tbg from ~7736' to Surface. M/U test equipment, set test plug. Test BOPE to 250 low/3500 high with 4 and 4 1/2" test jts per sundry. 6/22/2025 T/I/O = 0/0/0 RWO Decompletion MU 5" DP to 4-1/2" IF box x 7" IJ4S x/o, MU LJ to hanger, verify IA is open, BOLDS to 3-1/2" C/B minimum, pull tubing hanger to rig floor, cap 1/4" control lines x2, LD FMC 6 seal tubing hanger (scrap), RDMO 6/23/2025 Cont to test BOPE with 4" and 4 1/2" test jts to 250 low/3500 high per sundry, AOGCC waived witness (Austin McLeod) Zero Failures, 4 hr Test Time. R/D test equipment and pull test plug. M/U Yellow jacket 5 1/8" Smooth OD String Mill BHA. Single in hole P/U 4" DP from 233'. Pass through top of 7" cut jt with no issues. Tag 7" Casing collapse at 7,824'. Begin Swedging operations utilizing bumper sub. Hammer down with 10-20k on bumper sub from 7823' to 7824' 6/24/2025 Cont to POOH to 233'. Stand back BHA, inspect mill and bull nose, slight scarring on bull nose up to connection with mill. Remove bull nose and M/U 5" swedge, M/U BHA and 2 additional 6 3/4" DC's. TIH with 4" DP from 294'. Tag top of collapse @ 7826'. Attempt to Swedge 7" Casing from 7826' utilizing Bumper Sub. Bump down on swedge with 30-40k with little to no over pulls on up stroke. Decision made to POOH for Mill Assy. Verify Tag @ 7826' prior to POOH. POOH racking back 4" DP from 7826' . L/D BHA as Per YJ Rep.P/U 4 3/4" milling BHA and TIH, work mill through collasped casing to 7846' Mill passed cleanly with no set downs 6/25/2025 Work mill through collapsed casing with no set downs or increase in tq, POOH and P.U 5 1/2" milling BHA, TIH and work through Collapsed casing with NO set downs or increase in tq. Cont to work down and tag top of 4 1/2" tubing at 8190'. POOH and L/D BHA, P/U cleanout BHA,and TIH 6/26/2025 POOH L/D DP and BHA, R/U TRS and run completion per tally to 6206' Daily Report of Well Operations PBU J-10B 6/27/2025 T/I/O=0/0/0 RWO Completion Land hanger, run in lock down screws, set 6-3/8" J plug, clean void, install new BX- 160, grease hanger neck ID & OD, install THA (SBMS still inside THA), test void 500 psi/5 min., 5000 psi/10 min, good tests, bleed off, stand by for tree test, pull J plug, RDMO Final T/I/O=0/0/0 6/27/2025 Cont to run completion and land hanger EOT at 8170, spot 422 inhibited seawater down IA, Set packer MIT 4 1/2" tubing to 3000 psi for 30 min, IP 3259, 15 min 3232, FP 3222, MIT 9 5/8" IA to 2600 psi for 30 min, IP 2727, 15 min 2710, FP 2704, toal bbls pumped 5.9, BBls returned 5.9, N/D BOP and N/U tree, test void and tree to 500 low/ 5000 high for 5 min each, R/U and freexe protect well and allow to u-tube, Final pressure tubing =0, IA =0, Demob rig 6/27/2025 Assist I RIG w/ Freeze Protect (RWO) Pumped 145 bbls of 50* DSL down IA. Rig in control of well per LRS departure. 6/30/2025 T/I/O=0/0/0. Post RWO. Remove tree cap assembly and installed 6" x 7" CIW upper tree with SH-3000. Torque flanges to spec. PT upper tree against MV to 300/5000 psi. Pass. Install new 6" TPV, production piping, tree work platforms and set wellhouse and floor. ***Job Complete*** Final WHP's 0/0/0. 6/30/2025 ***WELL S/I ON ARRIVAL*** PULL BALL & ROD @ 7,7,44' SLM PULL RK-DGLV FROM ST.# 3 @ 5,980' MD PULL RK- DCR FROM ST.# 4 @ 3,830' MD ATTEMPT TO SET TOP STATION, DROPPED VALVE RAN KJ, 4-1/2" BRUSH, DOUBLE KJ, GUTTED 2-1/2" JD, RECOVERED DROPPED VALVE RAN KJ, 4-1/2" BRUSH, 4-1/2" OM-1 W/ POCKET POKER BRUSH, BRUSH POCKET IN ST.# 4 @ 3,830' MD ***WSR CONTINUED ON 01-JUL-2025*** 7/1/2025 ***CONTINUE FROM 6/30/25*** SET RK-DOME 16/64"ports,TRO 1500 PSI IN ST.# 4 @ 3830' MD SET RK-S/O (20/64" ports) IN ST.# 3 @ 5,980' MD PULL RHC @ 7,767' MD PULLED JUNK CATCHER FROM 8,254' MD PERFORMED MAN DOWN DRILL W/ CO REP ATTEMPTED TO LATCH PRONG @ 8,254' MD 2 RUNS W/ 3" PUMP BAILER TO 8,232' SLM. RECOVERED ~1-1/4 GALLONS OF SAND & MUD PULLED PRONG FROM 8,254' MD 2 RUNS W/ 3" PUMP BAILER TO PLUG BODY @ 8,254' MD. RECOVERED 4 CUPS OF SAND & MUD. FISHING NECK MARKS ON BOTTOM RAN 2-1/2" PUMP BAILER 3 TIMES TO 8,254' MD RECOVERED 1.5 GALS. OF FILL RAN 2-1/4" PUMP BAILER TO 8,254' MD RECOVERED 1/4 CUP OF FILL, METAL MARKS ON BOTTOM RAN 2-1/4" PUMP BAILER W/ SNORKEL S/D @ 8,254' MD (SAW A PSI CHANGE) ***CONTINUE 7/2/25*** Daily Report of Well Operations PBU J-10B 7/2/2025 ***CONTINUE FROM 7/1/25*** RAN 4-1/2" GR S/D @ 8,254' MD (SHEARED GR) RAN 4-1/2" DOGLESS GS S/D @ 8,254' MD PULLED PLUG BODY FROM 8273' MD ***WELL LEFT S/I ON DEPARTURE*** Logs@gsaloganalysis.com Production Log Analysis Report Company: Hilcorp North Slope, LLC Well Name: Beaver Creek Unit 24 Field: Beaver Creek County, State: Kenai Peninsula, Alaska API: 50-133-20639 PL Log Date: September 26, 2025 Logged By: Hannah Stier Logging Company: Alaska E-Line Services PLA Date: September 27, 2025 Log Analyst: Matt Gill Client: Hilcorp North Slope, LLC Well Name: Beaver Creek Unit 24 BY: Matt Gill Page 2 of 17 Table of Contents 1. PL Analysis ....................................................................................................................................................................... 3 1.1 Objectives .............................................................................................................................................................. 3 1.2 Overview ................................................................................................................................................................ 3 1.2.1 Casing Size: ........................................................................................................................................................ 3 1.2.2 Perforations: ...................................................................................................................................................... 3 1.2.3 Reported Rates: ................................................................................................................................................. 3 1.2.4 PVT: ................................................................................................................................................................... 3 1.3 PL Analysis Process ................................................................................................................................................ 4 1.3.1 QAQC Process .................................................................................................................................................... 4 1.3.2 VAPP Computation ............................................................................................................................................ 6 1.3.3 Rates Computation ............................................................................................................................................ 8 1.3.4 Conclusion ......................................................................................................................................................... 9 1.4 Results ................................................................................................................................................................. 11 1.4.1 Flowrate Results for Surface Rate 1 Survey – By Perforations ........................................................................ 11 1.5 Well Schematics ................................................................................................................................................... 15 1.6 Rate Log Mnemonics ........................................................................................................................................... 16 Disclaimers: All interpretations are opinions based on inferences from electrical or other measurements and we cannot and do not guarantee the accuracy or correctness of any interpretation, and we shall not, except in the case of gross or willful negligence on our part, be liable or responsible for any loss, costs, damages or expenses incurred or sustained by anyone resulting from any interpretations made by any of our officers, agents or employees. These interpretations ae also subject to our general terms and conditions. Client: Hilcorp North Slope, LLC Well Name: Beaver Creek Unit 24 BY: Matt Gill Page 3 of 17 1. PL Analysis 1.1 Objectives To interpret the production log data for Beaver Creek Unit 24 well for each perforation. Single survey with multiple up and down passes were run at logging speeds of 40, 80, 120, and 160 FPM to obtain PL data at a surface production rate, using 1-11/16” PL tool string. The PL tool string consisted of Gamma Ray, Casing Collar Locator, Capacitance, Temperature, Pressure, Inline Continuous Flowmeter, and Full- Bore Flowmeter tools. PL data from these tools were used to resolve the following: x Amounts of contributions from each zone interval x Contribution from each zone interval by phase type 1.2 Overview 1.2.1 Casing Size: OD: 5.5” Weight: 17# ID: 4.892” 1.2.2 Perforations: Total 35 Perforations 1.2.3 Reported Rates: Rate 1: 350 MSCFPD, 40 BWPD @ 65 PSI 1.2.4 PVT: Gas SG: 0.56 Oil API: NA Water Salinity: 25000 PPM Flow Model: 2 Phase L-G Correlations: Dukler Correlation (w-o): N/A Client: Hilcorp North Slope, LLC Well Name: Beaver Creek Unit 24 BY: Matt Gill Page 4 of 17 1.3 PL Analysis Process 1.3.1 QAQC Process All data collected from various up and down passes for each surface rate was analyzed. During the initial analysis process, logging speed, data units were checked. Based on GR curve, the depth of each pass was correlated to each other. Each pass was looked at individually for any anomalies, spikes. Flowmeter data was filtered to remove any yo-yo effect due to tension pulls during logging. Note: Beside Up pass 3, the capacitance tool seems to be fully saturated with water, therefore only capacitance up pass 3 was used for analysis reporting. Client: Hilcorp North Slope, LLC Well Name: Beaver Creek Unit 24 BY: Matt Gill Page 5 of 17 Figure showing log data after QAQC process for surface rate 1 survey. Client: Hilcorp North Slope, LLC Well Name: Beaver Creek Unit 24 BY: Matt Gill Page 6 of 17 1.3.2 VAPP Computation Spinner calibration was performed to compute vapp. During spinner calibration spinner slopes and thresholds were calculated for vapp. Figure showing spinner calibration for surface rate 1 survey for continuous (CFBFLOW) spinner data. Client: Hilcorp North Slope, LLC Well Name: Beaver Creek Unit 24 BY: Matt Gill Page 7 of 17 Figure showing spinner calibration for surface rate 1 survey for full-bore (HTFLOW) spinner data. Client: Hilcorp North Slope, LLC Well Name: Beaver Creek Unit 24 BY: Matt Gill Page 8 of 17 1.3.3 Rates Computation Once vapp was calculated, continuous (CFBFLOW) spinner data and full-bore (HTFFLOW) spinner data was used to calculate velocity curve using vapp data. Figure showing Velocity, Density and Capacitance match curves for rate computation for surface rate 1 survey. Client: Hilcorp North Slope, LLC Well Name: Beaver Creek Unit 24 BY: Matt Gill Page 9 of 17 1.3.4 Conclusion Based on tool data, provided PVT values, fluid mixture of gas and water, Vapp, 2 Phase Liquid- Gas flow model using Dukler correlation, the best predicted correlation matches were computed shown in figures below. Figure showing computed matches and flow rates for surface rate 1 survey. Client: Hilcorp North Slope, LLC Well Name: Beaver Creek Unit 24 BY: Matt Gill Page 10 of 17 Figure showing flowing station stop data for surface rate 1 survey. Client: Hilcorp North Slope, LLC Well Name: Beaver Creek Unit 24 BY: Matt Gill Page 11 of 17 1.4 Results Based on PLA following rates were calculated. Rate 1: Gas: 548.10 MSCF/D Water: 59.77 STB/D 1.4.1 Flowrate Results for Surface Rate 1 Survey – By Perforations Note: The flow rates of 0.00 show either no flowrate or inconclusive rates due to fluid rate and mixture fluctuations recorded by spinner and capacitance tool. Zone Contributions at S.C by Phase. Client: Hilcorp North Slope, LLC Well Name: Beaver Creek Unit 24 BY: Matt Gill Page 12 of 17 Zone Contributions at Reservoir Client: Hilcorp North Slope, LLC Well Name: Beaver Creek Unit 24 BY: Matt Gill Page 13 of 17 Client: Hilcorp North Slope, LLC Well Name: Beaver Creek Unit 24 BY: Matt Gill Page 14 of 17 Client: Hilcorp North Slope, LLC Well Name: Beaver Creek Unit 24 BY: Matt Gill Page 15 of 17 1.5 Well Schematics Client: Hilcorp North Slope, LLC Well Name: Beaver Creek Unit 24 BY: Matt Gill Page 16 of 17 1.6 Rate Log Mnemonics QZXT for total rate, where Z stands for zoned X is a letter representing the phase: O=Oil, G=Gas, W=Water T stands for Total QZXI for incremental, where Z stands for zoned X is a letter representing the phase: O=Oil, G=Gas, W=Water I stands for Incremental QZXTR for cumulative ratio, where Z stands for zoned X is a letter representing the phase: O=Oil, G=Gas, W=Water T stands for Total R stands for Ratio Blue color represent Water Green color represent oil Red color represent gas Client: Hilcorp North Slope, LLC Well Name: Beaver Creek Unit 24 BY: Matt Gill Page 17 of 17 Logs@gsaloganalysis.com Thank you for using GSA Log Analysis & Consulting. Nolan Valhovich Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 10/20/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 24 (PTD 214-112) PPROF 9/26/25 Please include current contact information if different from above. 214-112 T41017 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.10.20 13:23:00 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/02/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251002 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 11A 50133205210100 224123 9/23/2025 YELLOWJACKET PERF T40937 BCU 13 50133205250000 203138 8/18/2025 YELLOWJACKET GPT-PERF T40938 BCU 13 50133205250000 203138 8/26/2025 YELLOWJACKET GPT-PERF T49038 BCU 13 50133205250000 203138 8/21/2025 YELLOWJACKET GPT-PLUG T40938 BCU 23 50133206350000 214093 9/10/2025 YELLOWJACKET PERF T40939 BCU 24 50133206390000 214112 9/16/2025 YELLOWJACKET PLUG-PERF T40940 BRU 212-35T 50283200970000 198161 9/18/2025 AK E-LINE Perf T40941 BRU 224-34T 50283202050000 225044 7/29/2025 AK E-LINE CBP/Punch T40942 BRU 224-34T 50133207170000 225044 9/19/2025 AK E-LINE GPT/Perf T40942 END 1-05 50029216050000 186106 9/25/2025 YELLOWJACKET IPROF T40943 END 2-08 50029217710000 188004 8/11/2025 YELLOWJACKET PERF T40944 END 4-50 50029219400000 189044 9/8/2025 YELLOWJACKET P-PROF T40945 KBU 11-08Z 50133206290000 214044 9/15/2025 AK E-LINE Perf T40946 KU 33-08 50133207180000 224008 7/1/2025 YELLOWJACKET PERF T40947 KU 41-08 50133207170000 224005 8/28/2025 YELLOWJACKET PERF T40948 KU 41-08 50883201990100 224005 9/16/2025 AK E-LINE Perf T40948 MPU R-108 50029238210000 225062 8/14/2025 YELLOWJACKET SCBL T40949 MRU K-06RD2 50733200880200 216131 9/12/2025 AK E-LINE CBL T40950 MRU M-01 50733203880000 187046 9/20/2025 AK E-LINE Perf T40951 MRU M-25 50733203910000 187086 9/21/2025 AK E-LINE Perf T40952 NCIU A-21A 50883201990100 225075 8/21/2025 AK E-LINE CBL T40953 NFU 14-25 50231200350000 210111 9/3/2025 YELLOWJACKET PERF T40954 PBU PTM P1-08A 50029223840100 202199 9/13/2025 YELLOWJACKET SCBL T40955 PBU W-35A 50029217990200 225076 9/17/2025 YELLOWJACKET SCBL T40956 SRU 241-33 50133206630000 217047 9/17/2025 AK E-LINE Perf T40957 SRU 32A-33 50133101640100 191014 9/23/2025 AK E-LINE Perf T40958 SRU 32A-33 50133101640100 191014 9/21/2025 AK E-LINE Perf T40958 Please include current contact information if different from above. BCU 24 50133206390000 214112 9/16/2025 YELLOWJACKET PLUG-PERF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.10.03 09:00:56 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 08/26/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250826 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 24 50133206390000 214112 7/15/2025 AK E-LINE PPROF T40803 BR 11-86 50733207370000 225057 7/30/2025 AK E-LINE Hoist T40804 BR 11-86 50733207370000 225057 8/4/2025 AK E-LINE Perf T40804 BR 11-86 50733207370000 225057 8/9/2025 AK E-LINE Perf T40804 BRU 212-35T 50283200970000 198161 8/4/2025 AK E-LINE Perf T40805 BRU 212-35T 50283200970000 198161 6/28/2025 AK E-LINE Perf T40805 BRU 224-34T 50283202050000 225044 8/2/2025 AK E-LINE CBL T40806 BRU 224-34T 50283202050000 225044 8/5/2025 AK E-LINE CBL T40806 BRU 224-34T 50283202050000 225044 7/27/2025 AK E-LINE CBL T40806 BRU 224-34T 50283202050000 225044 8/2/2025 AK E-LINE Punch T40806 KTU 43-6XRD2 50133203280200 205117 7/26/2025 AK E-LINE Perf T40807 MPL-13A 50029223350100 223017 8/10/2025 READ CaliperSurvey T40808 NCIU A-21 50883201990000 224086 1/14/2025 AK E-LINE Plug/Perf T40809 ODSN-16 50703206200000 210053 8/10/2025 READ CaliperSurvey T40810 PBU 01-30A 50029216060100 225050 8/7/2025 HALLIBURTON RBT-COILFLAG T40811 PBU 06-11A 50029204280100 225042 7/13/2025 HALLIBURTON RBT-COILFLAG T40812 PBU 11-37A 50029227160100 219062 7/27/2025 HALLIBURTON RBT T40813 PBU 14-43A 50029222960100 225041 7/31/2025 HALLIBURTON RBT-COILFLAG T40814 PBU F-06B 50029200970200 225054 8/5/2025 HALLIBURTON RBT-COILFLAG T40815 PBU L1-10A 50029213400100 225032 8/1/2025 HALLIBURTON RBT-COILFLAG T40816 PCU 02A 50283200220100 224110 7/27/2025 AK E-LINE Perf T40817 SRU 241-33 50133206630000 217047 7/28/2025 AK E-LINE Perf T40818 WhiskeyGulch 1 50231200790000 221046 6/18/2025 AK E-LINE Packer T40819 Please include current contact information if different from above. T40803BCU 24 50133206390000 214112 7/15/2025 AK E-LINE PPROF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.08.27 08:12:23 -08'00' 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: CTCO, N2 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number):10. Field: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 11,300'N/A Casing Collapse Structural Conductor Surface 3,090 psi Intermediate Production 7,460 psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Ryan LeMay, Operations Engineer Contact Email:ryan.lemay@hilcorp.com Contact Phone: 661-487-0871 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 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 and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028083 214-112 50-133-20639-00-00 Hilcorp Alaska, LLC Proposed Pools: 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 N/A TVD Burst N/A 10,640 psi 2,933' 70' 3,187' MD See Attached Schematic 5,750 psi 70'70' 3,187' September 4, 2025 N/A 11,284' Perforation Depth MD (ft): 9-5/8" Beaver Creek Unit (BCU) 24CO 237D Same 10,681'5-1/2" ~2,888 psi Beaver Creek Beluga Gas, Tyonek Gas Size See Attached Schematic 11,284' See Schematic Length Swell Pkr: N/A 2,993' MD / 2,762' TVD; N/A 10,697'10,045'9,442' 16" m n P s t 2 N 66 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:28 am, Aug 21, 2025 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.08.20 17:27:34 - 08'00' Noel Nocas (4361) 325-497 DSR-8/26/25SFD 8/27/2025 Perforate 10-404 BJM 9/2/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.09.02 16:41:45 -08'00'09/02/25 RBDMS JSB 090425 Well Prognosis Well: BCU-24 Well Name: BCU-24 API Number: 50-133-20639-00 Current Status: Gas Producer Permit to Drill Number: 214-112 Regulatory Contact: Donna Ambruz (907) 777-8305 First Call Engineer: Ryan LeMay (661)487-0871 (M) Second Call Engineer: Scott Warner (907) 830-8863 (M) (907) 564-4506 (O) Maximum Expected BHP: 3763 psi @ 8750’ TVD Based on 0.43 psi/ft Max. Potential Surface Pressure:2888 psi Based on 0.1 psi/ft gas gradient to surface Applicable Frac Gradient: 0.61 psi/ft using 11.8 ppg EMW LOT at 9-5/8” shoe Shallowest Allowable Perf TVD: MPSP / (0.61 - 0.1) = 2888 psi / 0.51 = 5663’ TVD Top of Applicable Gas Pool / PA: Beluga Gas Pool / PA – 6472’ MD / 5880’ TVD Tyonek Gas Pool / PA – 9357’ MD / 8753’ TVD Well Status: Gas Producer x 491 mcfd / 68 psi FTP (As of 8/18/2025) Recent Well Summary: BCU- 24 is an active gas producer with multiple sets of open perforations across the Tyonek and Beluga Gas Pools / PAs. This well has commingled production in the Tyonek / Beluga from the Bel 23 – T-8 zones currently. The most recent perforations were added in August of 2024 where production increase from roughly 380 mcfd to 700 mcfd after perforations. Since, the well has slowly declined with a current rate of 491 mcfd as of 8/18/2025. Most recent well work completed on the well was the annual PLT for commingled zones in July of 2025. PLT analysis showed that roughly 97% of well production was coming from the Beluga zones and 3% of the well production from the Tyonek zones. The objective of this Sundry is to add additional perforations in the Beluga Gas Pool / PA (Bel 16 – T1). Procedure: 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250 psi low / 3,500 psi high 3. RIH and perforate the following sands: Below are proposed targeted sands in order of testing (bottom/up), but additional sands may be added depending on results of these perfs, between the proposed top and bottom perfs Well Sand Top MD Btm MD Top TVD Btm TVD Interval BCU-24 BEL 16 +7,708’ +7,718’ ±7,106' ±7,116' ±10' BCU-24 BEL 16L +7,793’ +7,805’ ±7,191' ±7,203' ±12' BCU-24 BEL 18 +7,920’ +7,930’ ±7,318' ±7,327' ±10' BCU-24 BEL 18 +7,931’ +7,938’ ±7,328' ±7335' ±7' BCU-24 BEL 19 +7,950’ +7,955’ ±7,347' ±7,352' ±5' BCU-24 BEL 19 +7,987’ +7,992’ ±7,384' ±7,389' ±5' BCU-24 BEL 19 +7,999’ +8,005’ ±7,396' ±7,402' ±6' BCU-24 BEL 19 +8,015’ +8,018’ ±7,412' ±7,415' ±3' well has commingled production in the Tyonek / Beluga Well Prognosis Well: BCU-24 BCU-24 BEL 20 +8,034’ +8,049’ ±7,431' ±7,446' ±15' BCU-24 BEL 20 +8,054’ +8,058’ ±7,451' ±7,455' ±4' BCU-24 BEL 20 +8,061’ +8,071’ ±7,458' ±7,468' ±10' BCU-24 BEL 21 +8,210’ +8,215’ ±7,607' ±7,612' ±5' BCU-24 BEL 22 +8,235’ +8,253’ ±7,631' ±7,649' ±18' BCU-24 BEL 22 +8,262’ +8,272’ ±7,658' ±7,668' ±10' BCU-24 BEL 22 +8,273’ +8,288’ ±7,669' ±7,684' ±15' BCU-24 BEL 25 +8,417’ +8,423’ ±7,813' ±7,819' ±6' BCU-24 BEL 27 +8,524’ +8,535’ ±7,920' ±7,931' ±11' BCU-24 BEL 29L +8,833’ +8,842’ ±8,229' ±8,238' ±9' BCU-24 BEL 29L +8,845’ +8,853’ ±8,241' ±8,249' ±8' BCU-24 BEL 29L +8,857’ +8,862’ ±8,253' ±8,258' ±5' BCU-24 T1X +9,176’ +9,182’ ±8,572' ±8,578' ±6' BCU-24 T1X +9,207’ +9,210’ ±8,603' ±8,606' ±3' BCU-24 T1X +9,215’ +9,221’ ±8,611' ±8,617' ±6' BCU-24 T1X +9,309’ +9,315’ ±8,705' ±8,711' ±6' BCU-24 T1 +9,350’ +9,354’ ±8,746' ±8,750' ±4' a. Correlate using log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation b. Use Gamma/CCL to correlate c. Record tubing pressures before and after each perforating run at 5 min, 10 min, and 15 min intervals post perf shot (if using switched guns, wait 10 min between shots) d. Pending well production, all perf intervals may not be completed e. If any current or proposed zones produce sand and/or water or needs isolated, RIH and set plug above the perforations OR patch across the perforations i. Note: A CIBP may be used instead of WRP if it is determined that no cement is needed for operational purposes. 35ft will not be placed on each plug as these zones are close together. If possible, the CIBP will be set 50’ above of the top of the last perforated sand unless zones are too close together in which case the plug will be set within 50’. f. If necessary, use nitrogen or pad gas throughout operations to pressure up well during perforating or to depress water prior to setting a plug above perforations 4. Perform production log per CO 237D Rule 5(c) – Downhole commingling within 30 days of stabilized flow. 5. RDMO. Well Prognosis Well: BCU-24 Contingency Procedure: Coiled Tubing Cleanout 1. If throughout the job any current or proposed zones produce sand and / or water that cannot be depressed and pushed away with nitrogen or pad gas, a coil tubing unit may be rigged up to clean out fill or fluid blown down as necessary. a. MIRU Fox CTU, PT BOPE to 250 psi low / 3500 psi high i. Provide AOGCC 24hrs notice of BOP test. b. Cleanout wellbore fill and / or blowdown well with nitrogen if necessary. Attachments: 1. Current Schematic 2. Proposed Schematic 3. Coil Tubing BOP Diagram 4. Standard Well Procedure – N2 Operations State/Prov:Alaska Country:USA Comingled production form Tyonek and Beluga Pools/PA's. Per CO 237C the well needs a production log every 12 months. Initial log obtained 6/16/22. 9/5/2024 Well Name & Number:Beaver Creek Unit #24 A - 028083 County or Parish:Kenai Peninsula Borough Lease: Revised By:Schematic Revision Date:Scott Warner BCU - 24 Pad 3 1,127 FNL, 1,645' FWL, Sec. 34, T7N, R10W, S.M. TD: 11,300' MD 10,697' TVD Permit #:214-112 API #:50-133-20639-00 Prop. Des:FED A-028083 KB elevation:179.2' (18.6' AGL) Lat:N60° 39' 30.871" Long:W151° 1' 2.842" Spud:9/22/2014 16:00 hrs TD:10/09/2014 06:00 hrs Rig Released:10/16/2014 16:00 hrs PBTD: 10,045' MD 9,442'TVD SCHEMATIC 1 Production Casing 5-1/2" P-110 17 ppf CDC Top Bottom MD 0' 11,284' TVD 0' 10,681' 8-1/2" hole Cmt w/ 1,945sks ( 471 bbls) of 15.3 ppg, Class G cmt w/ EASYBLOK Tree cxn = 9-1/2" Otis 8.0" Seal Diameter 5-1/8" Modified ID Bore Casing/Cementing Detail - 10.4 ppg Mud - 11.5 ppg Mud Push (35 bbl) - 15.3 ppg Cement (471 bbl) - 8.5 ppg 3% KCl (255 bbl) Max Dogleg: 6.59°/100' @ 1,034' Max Inclination: 29.4° @ 2,826' RA Mkr Jt 10,837' RA Mkr Jt 11,102' Casing Shoe @ 11,284' Conductor 16" X-56 109 ppf Top Bottom MD 0' 70' TVD 0' 70' Surface Casing 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 3,187' TVD 0' 2,933' 12-1/4" hole Lead Cmt w/ 525 sks (230 bbls) of 12.0 ppg, Class G, Tail Cmt w/ 230 sks (50 bbls) of 15.4 ppg, Class G, 180 sks (78 bbls) to surface Jewelry 1. Swell Packer (21' Long) 2. CIBP (capped w/ 19.5' cement 3/14/22) 3. CIBP (Capped w/ 35' cement 02/16/18) 4. CIBP (w/ 36' of cement 02/17/15) 5. CIBP (Set 11/18/14; Possibly leaking) Depth 2,993' 10,045' 10,900' 11,122' 11,130' TOC (CBL 10/30/14) - 2,584' RA Mkr Jt 8,934' RA Mkr Jt 9,825' RA Mkr Jt 8,172' RA Mkr Jt 8,624' RA Mkr Jt 5,799' RA Mkr Jt 7,948'PERFORATIONS: Zone MD TVD Amt Sz Date Status BEL 23 8303-8313 7699-7700 10 2-7/8" 08/20/24 Open BEL 23 8329-8343 7726-7740 14 2-7/8" 08/20/24 Open BEL 24 8347-8365 7744-7762 18 2-7/8" 08/20/24 Open BEL 25 8393-8408 7790-7805 15 2-7/8" 08/20/24 Open BEL 26 8454-8465 7851-7862 11 2-7/8" 05/26/22 Open BEL 26 8490-8498 7886-7895 8 2-7/8" 05/26/22 Open BEL 27 8544-8549 7940-7946 5 2-7/8" 05/26/22 Open BEL 27 8560-8582 7957-7979 22 2-7/8" 05/26/22 Open BEL 27 8591-8596 7988-7993 5 2-7/8" 05/26/22 Open BEL 28 8645-8665 8042-8062 20 2-7/8" 05/26/22 Open BEL 28 8685-8691 8082-8088 6 2-7/8" 08/19/24 Open BEL 28 8698-8703 8096-8100 5 2-7/8" 05/23/22 Open BEL 28L 8729-8743 8125-8139 14 2-7/8" 05/23/22 Open BEL 29 8774-8780 8171-8177 ±6 2-7/8" 08/19/24 Open BEL 29 8787-8790 8184-8189 3 2-7/8" 05/23/22 Open BEL 29 8798-8808 8195-8205 ±10 2-7/8" 08/19/24 Open BEL 30 8905-8909 8302-8306 4 2-7/8" 05/23/22 Open BEL 31 8934-8939 8332-8336 5 2-7/8" 05/23/22 Open BEL 32 8991-8996 8387-8393 5 2-7/8" 05/23/22 Open T-0 9244-9258 8641-8655 14 2-7/8" 08/19/24 Open T-1X 9328-9335 8725-8732 7 2-7/8" 03/15/22 Open T-1X 9328-9335 8725-8732 7 3-1/8" 03/28/22 Open T-3 9480-9484 8877-8881 4 3-1/8" 04/01/22 Open T-4 9581-9587 8978-8984 6 2-7/8" 08/19/24 Open T-5 9607-9613 9004-9010 6 2-7/8" 08/19/24 Open T-7A 9849-9863 9246-9260 14 2-7/8" 08/19/24 Open T-7A 9875-9889 9272-9286 14 2-7/8" 08/19/24 Open T-7B 9925-9945 9322-9342 20 2-7/8" 08/19/24 Open T-8 10013-10033 9410-9430 20 05/01/15 Open T-8 10013-10033 9410-9430 20 3-1/8" 03/28/22 Open T-8L 10071-10084 9468-9481 13 2-7/8" 03/14/22 Isolated T-15 10668-10672 10054-10059 4 2-7/8" 03/13/22 Isolated T-19 10960-10970 10357-10367 10 3-1/8" 02/16/18 Isolated T-20 11170-11180 10567-10577 10 3-1/8" 11/16/14 Isolated Tyonek T20 5 Tyonek T19 Tag @ 11,046' SLM (4/10/15) 4.60" Blind Box 4 T-8 T-8L T-15 3 RA Mkr Jt 10,837RRA Mk Jt 10 837RR'' 33 T-1X T-3 BEL 22 BEL 23 BEL 24 BEL 25 BEL 26 BEL 27 BEL 28 BEL 29 BEL 30 BEL 31 BEL 32 T0 2 Proposed Perforations: Well Sand Top MD Btm MD Top TVD Btm TVD Interval BCU-24 BEL 16 +7,708’ +7,718’ ±7,106' ±7,116' ±10' BCU-24 BEL 16L +7,793’ +7,805’ ±7,191' ±7,203' ±12' BCU-24 BEL 18 +7,920’ +7,930’ ±7,318' ±7,327' ±10' BCU-24 BEL 18 +7,931’ +7,938’ ±7,328' ±7335' ±7' BCU-24 BEL 19 +7,950’ +7,955’ ±7,347' ±7,352' ±5' BCU-24 BEL 19 +7,987’ +7,992’ ±7,384' ±7,389' ±5' BCU-24 BEL 19 +7,999’ +8,005’ ±7,396' ±7,402' ±6' BCU-24 BEL 19 +8,015’ +8,018’ ±7,412' ±7,415' ±3' BCU-24 BEL 20 +8,034’ +8,049’ ±7,431' ±7,446' ±15' BCU-24 BEL 20 +8,054’ +8,058’ ±7,451' ±7,455' ±4' BCU-24 BEL 20 +8,061’ +8,071’ ±7,458' ±7,468' ±10' BCU-24 BEL 21 +8,210’ +8,215’ ±7,607' ±7,612' ±5' BCU-24 BEL 22 +8,235’ +8,253’ ±7,631' ±7,649' ±18' BCU-24 BEL 22 +8,262’ +8,272’ ±7,658' ±7,668' ±10' BCU-24 BEL 22 +8,273’ +8,288’ ±7,669' ±7,684' ±15' BCU-24 BEL 25 +8,417’ +8,423’ ±7,813' ±7,819' ±6' BCU-24 BEL 27 +8,524’ +8,535’ ±7,920' ±7,931' ±11' BCU-24 BEL 29L +8,833’ +8,842’ ±8,229' ±8,238' ±9' BCU-24 BEL 29L +8,845’ +8,853’ ±8,241' ±8,249' ±8' BCU-24 BEL 29L +8,857’ +8,862’ ±8,253' ±8,258' ±5' BCU-24 T1X +9,176’ +9,182’ ±8,572' ±8,578' ±6' BCU-24 T1X +9,207’ +9,210’ ±8,603' ±8,606' ±3' BCU-24 T1X +9,215’ +9,221’ ±8,611' ±8,617' ±6' BCU-24 T1X +9,309’ +9,315’ ±8,705' ±8,711' ±6' BCU-24 T1 +9,350’ +9,354’ ±8,746' ±8,750' ±4' STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Development Exploratory 3. Address: Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11,300 feet See Schematic feet true vertical 10,697 feet N/A feet Effective Depth measured 10,045 feet N/A feet true vertical 9,442 feet N/A feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) N/A N/A N/A N/A Packers and SSSV (type, measured and true vertical depth) Swell Pkr; N/A 2,993' MD 2,762' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 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 Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: Scott Warner, Operations Engineer 324-437 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 396 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Noel Nocas, Operations Manager 907-564-5278 N/A scott.warner@hilcorp.com 907-564-4506 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 160 Size 70' 3 165639 0 641 69 Production Liner 11,284' measured TVD 5-1/2: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 214-112 50-133-20639-00-00 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Hilcorp Alaska, LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: FEDA028083 Beaver Creek / Beluga Gas, Tyonek Gas Beaver Creek (BCU) 24 Plugs Junk measured LengthCasing Structural 10,681'11,284' 70'Conductor Surface Intermediate 16" 9-5/8" 70' 3,187' 7,460psi 5,750psi 10,640psi 3,187' 2,933' Burst Collapse 3,090psi p k ft t Fra O s 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 8:28 am, Sep 13, 2024 Page 1/1 Well Name: BCU-024 Report Printed: 9/5/2024www.peloton.com Alaska Weekly Report - Operations Jobs Actual Start Date:8/19/2024 End Date: Report Number 1 Report Start Date 8/19/2024 Report End Date 8/20/2024 Last 24hr Summary PTW. PJSM. MIRU YJOS. T/I/O: 67/165/0 psi. MU 20' x 2-7/8" gun PT 250/3500 psi. RIH. FTP 63 psi. Perforate 20' T7B sands 9925 - 9945'. POH FTP 64 psi. RIH. FTP 63 psi. Perforate 14' T7A sands 9875 - 9889'. FTP 63. Perforate 14' T7A sands 9849 - 9863'. POH. FTP 63 psi. RIH. FTP 66 psi. Perforate 6' T5 sands 9607 -9613'. FTP 66 psi. Perforate 6' T4 sands 9581 - 9587'. FTP 65 psi. Perforate 14' TO sands 9244 - 9258'. POH. FTP 64 psi. RIH. FTP 63 psi. Perforate 10' BEL 29 sands 8798 - 8808'. FTP 63 psi. Perforate 6' BEL 29 sands 8774 - 8780'. FTP 65 psi. Perforate 6' BEL 28 sands 8685 - 8691'. POH. FTP 65 psi. RDFN. **Perf Guns 2-7/8" Geo Razor XDP 6 SPF 60* Phasing 15 gms** Report Number 2 Report Start Date 8/20/2024 Report End Date 8/21/2024 Last 24hr Summary PTW. PJSM. RIH w/ 2-3/4" x 15' gun. Perf BEL25 zone 8393' to 8408'. RIH w/ 2-3/4" x 18' gun. Perf BEL24 zone 8347' to 8365'. RIH w/ 2-3/4" x 14' gun. Perf BEL23 zone 8329' to 8343'. Switch. Perf BEL23 zone 8303' to 8313'. RDMO YJ EL BCU-024. Spot eqp. BCU-12A for tomorrow. Report Number 3 Report Start Date 8/22/2024 Report End Date 8/23/2024 Last 24hr Summary PTW. PJSM. RIG UP AK ELINE. PT 250/3500 PSI. DRIFT TO 9770' WITH 4.57" GAUGE RING. RIH WITH PRODUCTION LOGGING TOOLS. NO GOOD DATA DUE TO CLOGGED SPINNNERS. LAY DOWN FOR THE NIGHT. TO RESUME TOMORROW WITH ALTERNATE FBS. ***Cont. on 8/23/24*** Report Number 4 Report Start Date 8/23/2024 Report End Date 8/24/2024 Last 24hr Summary ***JOB CONTINUED FROM 22-AUGUST-2024*** AK ELINE. PTW. PJSM. RIG UP ELINE. WELL FLOWING AT 700 MSCFD AT 67 PSI. PERFORM DYNAMIC UP/DOWN PASSES OVER INTERVAL 8084' - 9692' AT 40, 80, 120, 160 FPM. PERFORM STATION SURVEYS AT 8130', 8630', 8880', 9150', 9290', 9400', 9530', AND 9690'. RIG DOWN ELINE. JOB COMPLETE. Field: Beaver Creek Sundry #: 324-437 State: ALASKA Rig/Service:Permit to Drill (PTD) #:214-112Permit to Drill (PTD) #:214-112 Wellbore API/UWI:50-133-20639-00-00 State/Prov:Alaska Country:USA Comingled production form Tyonek and Beluga Pools/PA's. Per CO 237C the well needs a production log every 12 months. Initial log obtained 6/16/22. Next PL log due by 8/23/25 9/5/2024 Well Name & Number:Beaver Creek Unit #24 A - 028083 County or Parish:Kenai Peninsula Borough Lease: Revised By:Schematic Revision Date:Scott Warner BCU - 24 Pad 3 1,127 FNL, 1,645' FWL, Sec. 34, T7N, R10W, S.M. TD: 11,300' MD 10,697' TVD Permit #:214-112 API #:50-133-20639-00 Prop. Des:FED A-028083 KB elevation:179.2' (18.6' AGL) Lat:N60°39' 30.871" Long:W151°1' 2.842" Spud:9/22/2014 16:00 hrs TD:10/09/2014 06:00 hrs Rig Released:10/16/2014 16:00 hrs PBTD: 10,045' MD 9,442'TVD SCHEMATIC 1 Production Casing 5-1/2" P-110 17 ppf CDC Top Bottom MD 0' 11,284' TVD 0' 10,681' 8-1/2" hole Cmt w/ 1,945sks ( 471 bbls) of 15.3 ppg, Class G cmt w/ EASYBLOK Tree cxn = 9-1/2" Otis 8.0" Seal Diameter 5-1/8" Modified ID Bore Casing/Cementing Detail - 10.4 ppg Mud - 11.5 ppg Mud Push (35 bbl) - 15.3 ppg Cement (471 bbl) - 8.5 ppg 3% KCl (255 bbl) Max Dogleg: 6.59°/100' @ 1,034' Max Inclination: 29.4°@ 2,826' RA Mkr Jt 10,837' RA Mkr Jt 11,102' Casing Shoe @ 11,284' Conductor 16" X-56 109 ppf Top Bottom MD 0' 70' TVD 0' 70' Surface Casing 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 3,187' TVD 0' 2,933' 12-1/4" hole Lead Cmt w/ 525 sks (230 bbls) of 12.0 ppg, Class G, Tail Cmt w/ 230 sks (50 bbls) of 15.4 ppg, Class G, 180 sks (78 bbls) to surface Jewelry 1. Swell Packer (21' Long) 2. CIBP (capped w/ 19.5' cement 3/14/22) 3. CIBP (Capped w/ 35' cement 02/16/18) 4. CIBP (w/ 36' of cement 02/17/15) 5. CIBP (Set 11/18/14; Possibly leaking) Depth 2,993' 10,045' 10,900' 11,122' 11,130' TOC (CBL 10/30/14) - 2,584' RA Mkr Jt 8,934' RA Mkr Jt 9,825' RA Mkr Jt 8,172' RA Mkr Jt 8,624' RA Mkr Jt 5,799' RA Mkr Jt 7,948'PERFORATIONS: Zone MD TVD Amt Sz Date Status BEL 23 8303-8313 7699-7700 10 2-7/8" 08/20/24 Open BEL 23 8329-8343 7726-7740 14 2-7/8" 08/20/24 Open BEL 24 8347-8365 7744-7762 18 2-7/8" 08/20/24 Open BEL 25 8393-8408 7790-7805 15 2-7/8" 08/20/24 Open BEL 26 8454-8465 7851-7862 11 2-7/8" 05/26/22 Open BEL 26 8490-8498 7886-7895 8 2-7/8" 05/26/22 Open BEL 27 8544-8549 7940-7946 5 2-7/8" 05/26/22 Open BEL 27 8560-8582 7957-7979 22 2-7/8" 05/26/22 Open BEL 27 8591-8596 7988-7993 5 2-7/8" 05/26/22 Open BEL 28 8645-8665 8042-8062 20 2-7/8" 05/26/22 Open BEL 28 8685-8691 8082-8088 6 2-7/8" 08/19/24 Open BEL 28 8698-8703 8096-8100 5 2-7/8" 05/23/22 Open BEL 28L 8729-8743 8125-8139 14 2-7/8" 05/23/22 Open BEL 29 8774-8780 8171-8177 ±6 2-7/8" 08/19/24 Open BEL 29 8787-8790 8184-8189 3 2-7/8" 05/23/22 Open BEL 29 8798-8808 8195-8205 ±10 2-7/8" 08/19/24 Open BEL 30 8905-8909 8302-8306 4 2-7/8" 05/23/22 Open BEL 31 8934-8939 8332-8336 5 2-7/8" 05/23/22 Open BEL 32 8991-8996 8387-8393 5 2-7/8" 05/23/22 Open T-0 9244-9258 8641-8655 14 2-7/8" 08/19/24 Open T-1X 9328-9335 8725-8732 7 2-7/8" 03/15/22 Open T-1X 9328-9335 8725-8732 7 3-1/8" 03/28/22 Open T-3 9480-9484 8877-8881 4 3-1/8" 04/01/22 Open T-4 9581-9587 8978-8984 6 2-7/8" 08/19/24 Open T-5 9607-9613 9004-9010 6 2-7/8" 08/19/24 Open T-7A 9849-9863 9246-9260 14 2-7/8" 08/19/24 Open T-7A 9875-9889 9272-9286 14 2-7/8" 08/19/24 Open T-7B 9925-9945 9322-9342 20 2-7/8" 08/19/24 Open T-8 10013-10033 9410-9430 20 05/01/15 Open T-8 10013-10033 9410-9430 20 3-1/8" 03/28/22 Open T-8L 10071-10084 9468-9481 13 2-7/8" 03/14/22 Isolated T-15 10668-10672 10054-10059 4 2-7/8" 03/13/22 Isolated T-19 10960-10970 10357-10367 10 3-1/8" 02/16/18 Isolated T-20 11170-11180 10567-10577 10 3-1/8" 11/16/14 Isolated Tyonek T20 5 Tyonek T19 Tag @ 11,046' SLM (4/10/15) 4.60" Blind Box 4 T-8 T-8L T-15 3 RA Mkr Jt 10,837RRA Mk Jt 10 837RR'' 33 T-1X T-3 BEL 22 BEL 23 BEL 24 BEL 25 BEL 26 BEL 27 BEL 28 BEL 29 BEL 30 BEL 31 BEL 32 T0 2 Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 9/9/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240909 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 24 50133206390000 214112 8/22/2024 AK E-LINE PPROF BRU 222-26 50283201950000 224035 7/16/2024 AK E-LINE Perf BRU 241-34S 50283201980000 224077 8/9/2024 AK E-LINE PPROF KBU 32-06 50133206580000 216137 8/17/2024 AK E-LINE PPROF KBU 32-06 50133206580000 216137 7/20/2024 AK E-LINE PPROF MPU L-54 50029236070000 218066 8/14/2024 READ Caliper Survey Please include current contact information if different from above. T39522 T39523 T39524 T39525 T39525 T39526 BCU 24 50133206390000 214112 8/22/2024 AK E-LINE PPROF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.09.09 12:37:48 -08'00' 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: N2 2.Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number):10. Field: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 11,300'N/A Casing Collapse Structural Conductor Surface 3,090 psi Intermediate Production 7,460 psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Swell Pkr: N/A 2,993' MD / 2,762' TVD; N/A 10,697'10,045'9,442' Beaver Creek Beluga Gas, Tyonek Gas 16" 9-5/8" See Attached Schematic 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Beaver Creek Unit (BCU) 24CO 237D Same 10,681'5-1/2" ~3,200 psi 11,284' See Schematic Length August 12, 2024 N/A 11,284' Perforation Depth MD (ft): See Attached Schematic 5,750 psi 70'70' 3,187' Size 70' 3,187' MD Hilcorp Alaska, LLC Proposed Pools: N/A TVD Burst N/A 10,640 psi 2,933' Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028083 214-112 50-133-20639-00-00 Tubing Size: PRESENT WELL CONDITION SUMMARY Scott Warner, Operations Engineer AOGCC USE ONLY Tubing Grade: scott.warner@hilcorp.com 907-564-4506 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 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 and Digital Signature with Date: m n P s 66 t N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:40 am, Jul 30, 2024 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.07.29 16:52:06 - 08'00' Noel Nocas (4361) 324-437 Perforate SFD 7/30/2024 DSR-7/31/24 10-404 BJM 8/5/24*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.08.05 15:16:04 -08'00'08/05/24 RBDMS JSB 080624 Well Prognosis Well: BCU-24 Well Name: BCU-24 API Number: 50-133-20639-00-00 Current Status: Producing Gas Well Permit to Drill Number: 214-112 Regulatory Contact: Donna Ambruz (907) 777-8305 First Call Engineer: Scott Warner (907) 564-4506 (O) (907) 830-8863 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (C) Maximum Expected BHP: 4140 psi @ 9410’ TVD Based on 0.44 psi/ft Max. Potential Surface Pressure: 3200 psi Based on 0.1 psi/ft gas gradient to surface Applicable Frac Gradient: 0.61 psi/ft using 11.8 ppg EMW FIT at the 9-5/8” surface casing shoe Shallowest Allowable Perf TVD: MPSP/(0.61-0.1) = 3200 psi / 0.51 = 6274‘ TVD Top of Applicable Gas Pool: 6472’ MD/ 5880’ TVD (Beluga) 9349’ MD/8746’ TVD (Tyonek) Well Status: Online Gas Producer flowing at 220 mcfd, 1 bwpd, 65 psi FTP Brief Well Summary Beaver Creek Unit #24 was drilled as a Grass roots monobore completion in 2014 to target gas sands in the Sterling, Lower Beluga, and Tyonek formations. The initial zone perforated in the Tyonek in mid-November was non-productive. This zone was plugged back and the next Tyonek interval (T-18) was perforated. This zone produced gas before hydrates began to form. The hydrates were treated with a capillary string, but the well eventually loaded up with fluid and has been unable to produce with the fluid level very near to surface. It is suspected that the bridge plug set between the T-20 and T-18 zones was leaking and contributing to the formation water loading up in the well. A bridge plug was set and effectively isolated the water from the T-20. The T-3 zone was re-perforated in May 2015 to reduce skin damage. Additional Tyonek perforations were added in 2022 which increased rate from 700 mscfd to 1000 mscfd. Beluga perforations were then added in May 2022. A production log that was ran in July 2023 showed gas contribution from most of the open perforations. The purpose of this sundry is to add additional perforations in both the Tyonek and Beluga pool to increase production. Once perforations are complete, a production log will be run in accordance with CO 237D, rule 5. Notes Regarding Wellbore Condition x Inclination o Max inclination = 29 degrees at 2825’ MD x Recent Tags o 7/15/23: EL tagged at 10,027’ and ran PLT log from 10,027 to 8,330 doing 30/60/90/120 ft/min passes with stop counts at 8350,8530,8630,8770,8880,9300,9800, and 10,000. Procedure: 1. MIRU E-line and pressure control equipment 2. PT lubricator to 250 psi low /3,500 psi high 3. RIH and perforate Tyonek 7B – Beluga 22 sands from bottom up with 2-7/8” 60 deg phased perf guns: , equivalent to 6,872' MD SFD Well Prognosis Well: BCU-24 Below are proposed targeted sands in order of testing (bottom/up), but additional sand may be added depending on results of these perfs, between the proposed top and bottom perfs Sand Top MD Btm MD Top TVD Btm TVD Interval BEL 22 8236 8246 ±7,633' ±7,643' ±10' BEL 22 8262 8272 ±7,659' ±7,669' ±10' BEL 22 8274 8281 ±7,671' ±7,678' ±7' BEL 23 8303 8313 ±7,699' ±7,709' ±10' BEL 23 8329 8343 ±7,726' ±7,740' ±14' BEL 24 8347 8365 ±7,744' ±7,762' ±18' BEL 25 8393 8408 ±7,790' ±7,805' ±15' BEL 27 8527 8534 ±7,924' ±7,931' ±7' BEL 28 8685 8691 ±8,082' ±8,088' ±6' BEL 29 8774 8780 ±8,171' ±8,177' ±6' BEL 29 8798 8808 ±8,195' ±8,205' ±10' BEL 29L 8836 8842 ±8,233' ±8,239' ±6' T0 9244 9258 ±8,641' ±8,655' ±14' T4 9581 9587 ±8,978' ±8,984' ±6' T5 9607 9613 ±9,004' ±9,010' ±6' T7A 9849 9863 ±9,246' ±9,260' ±14' T7A 9875 9889 ±9,272' ±9,286' ±14' T7B 9925 9945 ±9,322' ±9,342' ±20' a. Proposed perfs are also shown on the proposed schematic in red font b. Correlate using Open Hole Correlation Log provided by Geologist. Send the correlation pass to the Operations Engineer, Reservoir Engineer, and Geologist for confirmation c. Use Gamma/CCL to correlate d. Record Tubing pressures before and after each perforating run at 5 min, 10 min, and 15 min intervals post perf shot (if using switched guns, wait 10 min between shots) e. Pending well production, all perf intervals may not be completed f. If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations OR patch across the perforations i. Note: All proposed perforations are in the same Pools / Pa’s approved for commingled production. A CIBP may be used instead of WRP if it is determined that no cement is needed for operational purposes. 35ft will not be placed on each plug as these zones are close together. If possible, the CIBP will be set 50’ above of the top of the last perforated sand unless zones are too close together in which case the plug will be set within 50’. g. If necessary, use nitrogen to pressure up well during perforating or to depress water prior to setting a plug above perforations 4. RDMO 5. Once production has stabilized after adding perforations, a production log will be run in accordance with CO 237D, rule 5 Well Prognosis Well: BCU-24 Attachments: 1. Current Schematic 2. Proposed Schematic 3. Standard Well Procedure – N2 Operations State/Prov:Alaska Country:USA Comingled production form Tyonek and Beluga Pools/PA's. Per CO 237C the well needs a production log every 12 months. Initial log obtained 6/16/22. Next PL log due by 8/15/24 7/29/2024 Well Name & Number:Beaver Creek Unit #24 A - 028083 County or Parish:Kenai Peninsula Borough Lease: Revised By:Schematic Revision Date:Donna Ambruz BCU - 24 Pad 3 1,127 FNL, 1,645' FWL, Sec. 34, T7N, R10W, S.M. TD: 11,300' MD 10,697' TVD Permit #:214-112 API #:50-133-20639-00 Prop. Des:FED A-028083 KB elevation:179.2' (18.6' AGL) Lat:N60°39' 30.871" Long:W151°1' 2.842" Spud:9/22/2014 16:00 hrs TD:10/09/2014 06:00 hrs Rig Released:10/16/2014 16:00 hrs PBTD: 10,045' MD 9,442'TVD SCHEMATIC 1 Production Casing 5-1/2" P-110 17 ppf CDC Top Bottom MD 0' 11,284' TVD 0' 10,681' 8-1/2" hole Cmt w/ 1,945sks ( 471 bbls) of 15.3 ppg, Class G cmt w/ EASYBLOK Tree cxn = 9-1/2" Otis 8.0" Seal Diameter 5-1/8" Modified ID Bore Casing/Cementing Detail - 10.4 ppg Mud - 11.5 ppg Mud Push (35 bbl) - 15.3 ppg Cement (471 bbl) - 8.5 ppg 3% KCl (255 bbl) Max Dogleg: 6.59°/100' @ 1,034' Max Inclination: 29.4°@ 2,826' RA Mkr Jt 10,837' RA Mkr Jt 11,102' Casing Shoe @ 11,284' Conductor 16" X-56 109 ppf Top Bottom MD 0' 70' TVD 0' 70' Surface Casing 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 3,187' TVD 0' 2,933' 12-1/4" hole Lead Cmt w/ 525 sks (230 bbls) of 12.0 ppg, Class G, Tail Cmt w/ 230 sks (50 bbls) of 15.4 ppg, Class G, 180 sks (78 bbls) to surface Jewelry 1. Swell Packer (21' Long) 2. CIBP (capped w/ 19.5' cement 3/14/22) 3. CIBP (Capped w/ 35' cement 02/16/18) 4. CIBP (w/ 36' of cement 02/17/15) 5. CIBP (Set 11/18/14; Possibly leaking) Depth 2,993' 10,045' 10,900' 11,122' 11,130' TOC (CBL 10/30/14) - 2,584' RA Mkr Jt 8,934' RA Mkr Jt 9,825' RA Mkr Jt 8,172' RA Mkr Jt 8,624' RA Mkr Jt 5,799' RA Mkr Jt 7,948' PERFORATIONS: Zone MD TVD Amt Sz Date Status BEL 26 8454-8465 7851-7862 11 2-7/8" 05/26/22 Open BEL 26 8490-8498 7886-7895 8 2-7/8" 05/26/22 Open BEL 27 8544-8549 7940-7946 5 2-7/8" 05/26/22 Open BEL 27 8560-8582 7957-7979 22 2-7/8" 05/26/22 Open BEL 27 8591-8596 7988-7993 5 2-7/8" 05/26/22 Open BEL 28 8645-8665 8042-8062 20 2-7/8" 05/26/22 Open BEL 28 8698-8703 8096-8100 5 2-7/8" 05/23/22 Open BEL 28L 8729-8743 8125-8139 14 2-7/8" 05/23/22 Open BEL 29 8787-8790 8184-8189 3 2-7/8" 05/23/22 Open BEL 30 8905-8909 8302-8306 4 2-7/8" 05/23/22 Open BEL 31 8934-8939 8332-8336 5 2-7/8" 05/23/22 Open BEL 32 8991-8996 8387-8393 5 2-7/8" 05/23/22 Open T-1X 9328-9335 8725-8732 7 2-7/8" 03/15/22 Open T-1X 9328-9335 8725-8732 7 3-1/8" 03/28/22 Open T-3 9480-9484 8877-8881 4 3-1/8" 04/01/22 Open T-8 10013-10033 9410-9430 20 05/01/15 Open T-8 10013-10033 9410-9430 20 3-1/8" 03/28/22 Open T-8L 10071-10084 9468-9481 13 2-7/8" 03/14/22 Isolated T-15 10668-10672 10054-10059 4 2-7/8" 03/13/22 Isolated T-19 10960-10970 10357-10367 10 3-1/8" 02/16/18 Isolated T-20 11170-11180 10567-10577 10 3-1/8" 11/16/14 Isolated Tyonek T20 5 Tyonek T19 Tag @ 11,046' SLM (4/10/15) 4.60" Blind Box 4 T-8 T-8L T-15 3 RA Mkr Jt 10,837RRA Mk Jt 10 837RR'' 33 T-1X T-3 BEL 26 BEL 27 BEL 28 BEL 29 BEL 30 BEL 31 BEL 32 2 State/Prov:Alaska Country:USA Comingled production form Tyonek and Beluga Pools/PA's. Per CO 237C the well needs a production log every 12 months. Initial log obtained 6/16/22. Next PL log due by 8/15/24 7/29/2024 Well Name & Number:Beaver Creek Unit #24 A - 028083 County or Parish:Kenai Peninsula Borough Lease: Revised By:Schematic Revision Date:Donna Ambruz BCU - 24 Pad 3 1,127 FNL, 1,645' FWL, Sec. 34, T7N, R10W, S.M. TD: 11,300' MD 10,697' TVD Permit #:214-112 API #:50-133-20639-00 Prop. Des:FED A-028083 KB elevation:179.2' (18.6' AGL) Lat:N60°39' 30.871" Long:W151°1' 2.842" Spud:9/22/2014 16:00 hrs TD:10/09/2014 06:00 hrs Rig Released:10/16/2014 16:00 hrs PBTD: 10,045' MD 9,442'TVD PROPOSED 1 Production Casing 5-1/2" P-110 17 ppf CDC Top Bottom MD 0' 11,284' TVD 0' 10,681' 8-1/2" hole Cmt w/ 1,945sks ( 471 bbls) of 15.3 ppg, Class G cmt w/ EASYBLOK Tree cxn = 9-1/2" Otis 8.0" Seal Diameter 5-1/8" Modified ID Bore Casing/Cementing Detail - 10.4 ppg Mud - 11.5 ppg Mud Push (35 bbl) - 15.3 ppg Cement (471 bbl) - 8.5 ppg 3% KCl (255 bbl) Max Dogleg: 6.59°/100' @ 1,034' Max Inclination: 29.4°@ 2,826' RA Mkr Jt 10,837' RA Mkr Jt 11,102' Casing Shoe @ 11,284' Conductor 16" X-56 109 ppf Top Bottom MD 0' 70' TVD 0' 70' Surface Casing 9-5/8" L-80 40 ppf BTC Top Bottom MD 0' 3,187' TVD 0' 2,933' 12-1/4" hole Lead Cmt w/ 525 sks (230 bbls) of 12.0 ppg, Class G, Tail Cmt w/ 230 sks (50 bbls) of 15.4 ppg, Class G, 180 sks (78 bbls) to surface Jewelry 1. Swell Packer (21' Long) 2. CIBP (capped w/ 19.5' cement 3/14/22) 3. CIBP (Capped w/ 35' cement 02/16/18) 4. CIBP (w/ 36' of cement 02/17/15) 5. CIBP (Set 11/18/14; Possibly leaking) Depth 2,993' 10,045' 10,900' 11,122' 11,130' TOC (CBL 10/30/14) - 2,584' RA Mkr Jt 8,934' RA Mkr Jt 9,825' RA Mkr Jt 8,172' RA Mkr Jt 8,624' RA Mkr Jt 5,799' RA Mkr Jt 7,948'PERFORATIONS: Zone MD TVD Amt Sz Date Status BEL 22 ±8236-8246 ±7633-7643 ±10 2-7/8" Proposed TBD BEL 22 ±8262-8272 ±7659-7669 ±10 2-78" Proposed TBD BEL 22 ±8274-8281 ±7671-7678 ±7 2-78" Proposed TBD BEL 23 ±8303-8313 ±7699-7700 ±10 2-78" Proposed TBD BEL 23 ±8329-8343 ±7726-7740 ±14 2-78" Proposed TBD BEL 24 ±8347-8365 ±7744-7762 ±18 2-78" Proposed TBD BEL 25 ±8393-8408 ±7790-7805 ±15 2-78" Proposed TBD BEL 26 8454-8465 7851-7862 11 2-7/8" 05/26/22 Open BEL 26 8490-8498 7886-7895 8 2-7/8" 05/26/22 Open BEL 27 ±8527-8534 ±7924-7931 ±7 2-78" Proposed TBD BEL 27 8544-8549 7940-7946 5 2-7/8" 05/26/22 Open BEL 27 8560-8582 7957-7979 22 2-7/8" 05/26/22 Open BEL 27 8591-8596 7988-7993 5 2-7/8" 05/26/22 Open BEL 28 8645-8665 8042-8062 20 2-7/8" 05/26/22 Open BEL 28 ±8685-8691 ±8082-8088 ±6 2-78" Proposed TBD BEL 28 8698-8703 8096-8100 5 2-7/8" 05/23/22 Open BEL 28L 8729-8743 8125-8139 14 2-7/8" 05/23/22 Open BEL 29 ±8774-8780 ±8171-8177 ±6 2-78" Proposed TBD BEL 29 8787-8790 8184-8189 3 2-7/8" 05/23/22 Open BEL 29 ±8798-8808 ±8195-8205 ±10 2-78" Proposed TBD BEL 29L ±8836-8842 ±8233-8239 ±6 2-78" Proposed TBD BEL 30 8905-8909 8302-8306 4 2-7/8" 05/23/22 Open BEL 31 8934-8939 8332-8336 5 2-7/8" 05/23/22 Open BEL 32 8991-8996 8387-8393 5 2-7/8" 05/23/22 Open T-0 ±9244-9258 ±8641-8655 ±14 2-78" Proposed TBD T-1X 9328-9335 8725-8732 7 2-7/8" 03/15/22 Open T-1X 9328-9335 8725-8732 7 3-1/8" 03/28/22 Open T-3 9480-9484 8877-8881 4 3-1/8" 04/01/22 Open T-4 ±9581-9587 ±8978-8984 ±6 2-78" Proposed TBD T-5 ±9607-9613 ±9004-9010 ±6 2-78" Proposed TBD T-7A ±9849-9863 ±9246-9260 ±14 2-78" Proposed TBD T-7A ±9875-9889 ±9272-9286 ±14 2-78" Proposed TBD T-7B ±9925-9945 ±9322-9342 ±20 2-78" Proposed TBD T-8 10013-10033 9410-9430 20 05/01/15 Open T-8 10013-10033 9410-9430 20 3-1/8" 03/28/22 Open T-8L 10071-10084 9468-9481 13 2-7/8" 03/14/22 Isolated T-15 10668-10672 10054-10059 4 2-7/8" 03/13/22 Isolated Tyonek T20 5 Tyonek T19 Tag @ 11,046' SLM (4/10/15) 4.60" Blind Box 4 T-8 T-8L T-15 3 RA Mkr Jt 10,837RRA Mk Jt 10 837RR'' 33 T-1X T-3 BEL 26 BEL 27 BEL 28 BEL 29 BEL 30 BEL 31 BEL 32 2 STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 07/28/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230728 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU-23 50133206350000 214093 7/16/2023 HALLIBURTON PPROF BCU-24 50133206390000 214112 7/15/2022 HALLIBURTON PPROF BRU 223-34 50283201880000 223041 7/9/2023 HALLIBURTON RMT3D KBU 23X-6 50133203710000 184109 6/22/2023 HALLIBURTON EPX KBU 23X-6 50133203710000 184109 6/22/2023 HALLIBURTON MFC KGSF 7A 50133205380100 204163 6/18/2023 HALLIBURTON EPX KGSF 7A 50133205380100 204163 6/18/2023 HALLIBURTON MFC KU 21-6RD 50133100900100 201097 6/24/2023 HALLIBURTON EPX KU 21-6RD 50133100900100 201097 6/24/2023 HALLIBURTON MFC MPU B-24 50029226420000 196009 7/24/2023 HALLIBURTON WFL-TMD3D MPU B-34 50029235690000 216139 7/23/2023 HALLIBURTON WFL-TMD3D MPU B-50 50029232400000 204252 7/21/2023 HALLIBURTON WFL-TMD3D MPU E-23 50029225700000 195094 6/17/2023 HALLIBURTON COILFLAG MPU F-17 50029228230000 197196 7/2/2023 HALLIBURTON COILFLAG MPU L-13A 50029223350100 223017 6/21/2023 HALLIBURTON COILFLAG MPU L-39B 50029227860200 223037 6/30/2023 HALLIBURTON COILFLAG MPU L-39B 50029227860200 223037 6/30/2023 HALLIBURTON RBT PBU 11-07 50029206870000 181177 6/28/2023 HALLIBURTON RMT3D SCU 42-05X 50133205610000 206074 6/20/2023 HALLIBURTON EPX SCU 42-05X 50133205610000 206074 6/20/2023 HALLIBURTON MFC SCU 42-05Z 50133206950000 220069 6/16/2023 HALLIBURTON EPX SCU 42-05Z 50133206950000 220069 6/16/2023 HALLIBURTON MFC Please include current contact information if different from above. T37886 T37887 T37888 T37889 T37889 T37890 T37890 T37891 T37891 T37892 T37893 T37894 T37895 T37896 T37897 T37898 T37898 T37899 T37900 T37900 T37901 T37901 BCU-24 50133206390000 214112 7/15/2022 HALLIBURTON PPROF Kayla Junke Digitally signed by Kayla Junke Date: 2023.08.01 10:05:02 -08'00' 2SHUDWLRQV $EDQGRQ 3OXJ3HUIRUDWLRQV )UDFWXUH6WLPXODWH 3XOO7XELQJ 2SHUDWLRQVVKXWGRZQ 3HUIRUPHG 6XVSHQG 3HUIRUDWH 2WKHU6WLPXODWH $OWHU&DVLQJ &KDQJH$SSURYHG3URJUDP 3OXJIRU5HGULOO 3HUIRUDWH1HZ3RRO 5HSDLU:HOO 5HHQWHU6XVS:HOO 2WKHU 'HYHORSPHQW ([SORUDWRU\ 6WUDWLJUDSKLF 6HUYLFH $3,1XPEHU 3URSHUW\'HVLJQDWLRQ /HDVH1XPEHU :HOO1DPHDQG1XPEHU /RJV /LVWORJVDQGVXEPLWHOHFWURQLFGDWDSHU$$& )LHOG3RRO V 3UHVHQW:HOO&RQGLWLRQ6XPPDU\ 7RWDO'HSWK PHDVXUHG IHHW IHHW WUXHYHUWLFDO IHHW 1$ IHHW (IIHFWLYH'HSWK PHDVXUHG IHHW 1$ IHHW WUXHYHUWLFDO IHHW 1$ IHHW 3HUIRUDWLRQGHSWK 0HDVXUHGGHSWK 6HH6FKHPDWLF IHHW 7UXH9HUWLFDOGHSWK 6HH6FKHPDWLF IHHW 7XELQJ VL]HJUDGHPHDVXUHGDQGWUXHYHUWLFDOGHSWK 1$ 1$ 1$ 1$ 3DFNHUVDQG6669 W\SHPHDVXUHGDQGWUXHYHUWLFDOGHSWK 6ZHOO3NU 1$ 0' 79' 1$ 6WLPXODWLRQRUFHPHQWVTXHH]HVXPPDU\ ,QWHUYDOVWUHDWHG PHDVXUHG 7UHDWPHQWGHVFULSWLRQVLQFOXGLQJYROXPHVXVHGDQGILQDOSUHVVXUH 1$ 3ULRUWRZHOORSHUDWLRQ 6XEVHTXHQWWRRSHUDWLRQ :HOO&ODVVDIWHUZRUN 'DLO\5HSRUWRI:HOO2SHUDWLRQV ([SORUDWRU\ 'HYHORSPHQW 6HUYLFH 6WUDWLJUDSKLF &RSLHVRI/RJVDQG6XUYH\V5XQ :HOO6WDWXVDIWHUZRUN 2LO *DV :'63/ (OHFWURQLF)UDFWXUH6WLPXODWLRQ'DWD *6725 *,1-6863 63/8* 6XQGU\1XPEHURU1$LI&2([HPSW &RQWDFW1DPH &RQWDFW(PDLO $XWKRUL]HG7LWOH &RQWDFW3KRQH 6U3HW(QJ 6U3HW*HR 6U5HV(QJ $XWKRUL]HG1DPHDQG'LJLWDO 6LJQDWXUHZLWK'DWH :,1-:$* :DWHU%EO2LO%EO ,KHUHE\FHUWLI\WKDWWKHIRUHJRLQJLVWUXHDQGFRUUHFWWRWKHEHVWRIP\NQRZOHGJH 5\DQ5XSHUW2SHUDWLRQV(QJLQHHU U\DQUXSHUW#KLOFRUSFRP 'DQ0DUORZH2SHUDWLRQV0DQDJHU PHDVXUHG WUXHYHUWLFDO 3DFNHU 5HSUHVHQWDWLYH'DLO\$YHUDJH3URGXFWLRQRU,QMHFWLRQ'DWD &DVLQJ3UHVVXUH 7XELQJ3UHVVXUH $WWDFKPHQWV UHTXLUHGSHU$$& *DV0FI 0' 6WUXFWXUDO 79' 67$7(2)$/$6.$ $/$6.$2,/$1'*$6&216(59$7,21&200,66,21 5(32572)681'5<:(//23(5$7,216 1$ 3HUPLWWR'ULOO1XPEHU 2SHUDWRU1DPH :HOO&ODVV%HIRUH:RUN )('$ %HDYHU&UHHN8QGHI7\RQHN*DV3RRO +LOFRUS$ODVND//& &HQWHUSRLQW'U6XLWH $QFKRUDJH$. $GGUHVV %HDYHU&UHHN %&8 PHDVXUHG3OXJV -XQN PHDVXUHG 1$ /HQJWK 6L]H &RQGXFWRU 6XUIDFH ,QWHUPHGLDWH 3URGXFWLRQ /LQHU &DVLQJ SVL SVL SVL %XUVW &ROODSVH SVL W )UD 2 $ 3* 5 )RUP5HYLVHG6XEPLW:LWKLQGD\VRI2SHUDWLRQV By Samantha Carlisle at 9:12 am, Jul 15, 2022 'LJLWDOO\VLJQHGE\'DQ0DUORZH '1 FQ 'DQ0DUORZH RX 8VHUV 'DWH 'DQ0DUORZH ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ ϱͬϮϯͬϮϮ ϲͬϭϲͬϮϮ ϬϱͬϮϲͬϮϬϮϮͲdŚƵƌƐĚĂLJ WƌĞ:ŽďͲ^ĂĨĞƚLJŵĞĞƚŝŶŐĂŶĚĂĐƋƵŝƌĞƉĞƌŵŝƚƐ͘ŚĞĐŬǁĞůůƉƌĞƐƐƵƌĞϲϱϬͲƉƐŝĨůŽǁŝŶŐ͘D/ZhzĞůůŽǁ:ĂĐŬĞƚ Ͳ>ŝŶĞ͘ĂŶĚƚĞƐƚ ůƵďƌŝĐĂƚŽƌƚŽϮϱϬͲƉƐŝůŽǁĂŶĚϯϱϬϬͲƉƐŝŚŝŐŚ͘'/,ǁŝƚŚ Ͳ>ŝŶĞϭͲϭϭͬϭϲΗ'W>ƚŽŽůƐĂŶĚϱΖϮͲϳͬϴΗϲͲ^W&,^ŐƵŶƐ͕ĐŽƌƌĞůĂƚĞ ĂŶĚƉĞƌĨŽƌĂƚĞĨƌŽŵϴϱϵϭͲϴϱϵϲΖ͘DŽŶŝƚŽƌƉƌĞƐƐƵƌĞĂŶĚĨůŽǁĨŽƌϱ͕ϭϬ͕ϭϱͲŵŝŶ͘EŽĐŚĂŶŐĞWKK,ůĂŝĚĚŽǁŶƚŽŽůƐ͘ůůƐŚŽƚƐ ĨŝƌĞĚ͘ EŽƚĞ͗ŐƵŶƐǁĞƌĞǁĞƚĂŶĚďƵůůƉůƵŐŚĂĚĂďƵƌŶƚŐƵŶƉŽǁĚĞƌůŝƋƵŝĚŝŶŝƚƚŚĂƚƋƵŝĐŬůLJĞǀĂƉŽƌĂƚĞĚĨƌŽŵĚƵĐŬƉŽŶĚ͘'/, ǁŝƚŚ Ͳ>ŝŶĞϭͲϭϭͬϭϲΗ'W>ƚŽŽůƐĂŶĚϮϬΖϮͲϳͬϴΗϲͲ^W&,^ŐƵŶƐ͕ĐŽƌƌĞůĂƚĞĂŶĚƉĞƌĨŽƌĂƚĞĨƌŽŵϴϲϰϱͲϴϲϲϱΖ͘DŽŶŝƚŽƌ ƉƌĞƐƐƵƌĞĂŶĚĨůŽǁĨŽƌϱ͕ϭϬ͕ϭϱͲŵŝŶ͘ϴϬ<ŝŶĐƌĞĂƐĞŝŶĨůŽǁ͕WKK,ůĂŝĚĚŽǁŶƚŽŽůƐ͘ůůƐŚŽƚƐĨŝƌĞĚ͘ EŽƚĞ͗ŐƵŶƐǁĞƌĞĚƌLJĂŶĚďƵůůƉůƵŐŚĂĚĂũƵƐƚŐƵŶĚĞďƌŝƐŝŶŝƚ͘'/,ǁŝƚŚ Ͳ>ŝŶĞϭͲϭϭͬϭϲΗ'W>ƚŽŽůƐĂŶĚϮϮΖϮͲϳͬϴΗϲͲ^W& ,^ŐƵŶ͕ ^ǁŝƚĐŚ͕ϱΖϮͲϳͬϴΗϲ^W&,^ŐƵŶĐŽƌƌĞůĂƚĞĂŶĚƉĞƌĨŽƌĂƚĞĨƌŽŵϴϱϲϬΖͲϴϱϴϮΖ͕DŽŶŝƚŽƌƉƌĞƐƐƵƌĞĂŶĚĨůŽǁĨŽƌϱ ŵŝŶ͘ϳϭϳŵĐĨĚͬϲϰϱͲƉƐŝ͘ĨƚĞƌϭϬŵŝŶ͘ϲϵϰŵĐĨĚͬϲϰϲͲƉƐŝ͘WƵůůƵƉŚŽůĞ͕ĐŽƌƌĞůĂƚĞĂŶĚƉĞƌĨŽƌĂƚĞĨƌŽŵϴϱϰϰΖͲϴϱϰϵΖ DŽŶŝƚŽƌƉƌĞƐƐƵƌĞĂŶĚĨůŽǁĨŽƌϱŵŝŶ͘ƌĂƚĞƵƉƚŽϭϭϳϯŵĐĨĚͬϲϰϲсƉƐŝ͘ĂĨƚĞƌϭϬŵŝŶ͘ϭϯϰϰŵĐĨĚͬϲϱϮͲƉƐŝ͘WKK,ůĂŝĚ ĚŽǁŶƚŽŽůƐ͘ůůƐŚŽƚƐĨŝƌĞĚ͘ EŽƚĞ͗ŐƵŶƐǁĞƌĞĚƌLJĂŶĚďƵůůƉůƵŐŚĂĚŵĂLJďĞϭŽƵŶĐĞŽĨĚŝƌƚLJĨůƵŝĚŝŶŝƚ͘'/,ǁŝƚŚ Ͳ>ŝŶĞϭͲϭϭͬϭϲΗ'W>ƚŽŽůƐĂŶĚϴΖϮͲ ϳͬϴΗϲͲ^W&,^ŐƵŶ͕ ^ǁŝƚĐŚ͕ϭϮΖϮͲϳͬϴΗϲ^W&,^ŐƵŶĐŽƌƌĞůĂƚĞĂŶĚƉĞƌĨŽƌĂƚĞĨƌŽŵϴϰϵϬΖͲϴϰϵϴΖ͕DŽŶŝƚŽƌƉƌĞƐƐƵƌĞ ĂŶĚĨůŽǁĨŽƌϱ͕ϭϬŵŝŶ͘EŽĐŚĂŶŐĞ͘WƵůůƵƉŚŽůĞ͕ĐŽƌƌĞůĂƚĞĂŶĚƉĞƌĨŽƌĂƚĞĨƌŽŵϴϰϱϰΖͲϴϰϲϱΖDŽŶŝƚŽƌƉƌĞƐƐƵƌĞĂŶĚĨůŽǁ ĨŽƌϱ͕ϭϬŵŝŶ͘EŽĐŚĂŶŐĞ͘WKK,ůĂŝĚĚŽǁŶƚŽŽůƐ͘ůůƐŚŽƚƐĨŝƌĞĚ͘ EŽƚĞ͗ŐƵŶƐǁĞƌĞĚƌLJĂŶĚďƵůůƉůƵŐŚĂĚŵĂLJďĞϭŽƵŶĐĞŽĨĚŝƌƚLJĨůƵŝĚŝŶŝƚ͘ZŝŐĚŽǁŶǁŝƌĞůŝŶĞ͘ ϬϱͬϮϯͬϮϬϮϮͲDŽŶĚĂLJ z: >ĂƌƌŝǀĞŽŶůŽĐĂƚŝŽŶ͘WdtĂŶĚW:^D͘ZŝŐͲƵƉŽŶǁĞůůhͲϮϰ͘DhϱΖϮͲϳͬϴΗ,ŐƵŶǁͬ'Wd;ϭϯ͘ϱΖ>ƚŽƚŽƉƐŚŽƚͿ͘Wd ƚŽϮϱϬƉƐŝͬϯϱϬϬƉƐŝ͘Z/,͘WƵůů'WdůŽŐĨƌŽŵƚĂŐĂƚϭϬ͕ϬϯϴΖƚŽϵϯϬϬΖ͘WƵůůĐŽƌƌůŽŐĂŶĚƐĞŶĚƚŽƚŽǁŶ͕ŽŶĚĞƉƚŚ͘WĞƌĨŽƌĂƚĞ ƚŚĞĞůϯϮĨƌŽŵϴ͕ϵϵϭΖͲϴϵϵϲΖ͘WKK,͘WƌĞƐƐƵƌĞ/ŶŝƚŝĂůͲϲϯϬ͕ϱŵŝŶͲϲϯϬ͕ϭϬŵŝŶͲϲϯϬ͕ϭϱŵŝŶͲϲϯϬ͘&ůŽǁƌĂƚĞƐƚĂďůĞĂƚ ϰϲϮŵĐĨ͘>ĂLJĚŽǁŶŐƵŶ͕ĂůůƐŚŽƚƐĨŝƌĞĚ͕ŐƵŶǁĂƐǁĞƚ͘DhϱΖ͕ϰΖ͕ĂŶĚϯΖϮͲϳͬϴΗ,ŐƵŶƐ͘ƌŵĂŶĚZ/,͘WƵůůĐŽƌƌĞůĂƚŝŽŶůŽŐ͕ ƐĞŶĚƚŽƚŽǁŶ͕ŽŶĚĞƉƚŚ͘WĞƌĨŽƌĂƚĞƚŚĞĞůϯϭĨƌŽŵϴ͕ϵϯϰΖͲϴ͕ϵϯϵΖ͘WĞƌĨŽƌĂƚĞƚŚĞĞůϯϬĨƌŽŵϴ͕ϵϬϱΖͲϴ͕ϵϬϵΖ͘WĞƌĨŽƌĂƚĞƚŚĞ ĞůϮϵĨƌŽŵϴ͕ϳϴϳΖͲϴ͕ϳϵϬΖ͘WKK,͘WƌĞƐƐƵƌĞĂŶĚĨůŽǁƌĂƚĞƐƚĂLJĞĚƐƚĂďůĞĂƚϲϯϬƉƐŝ͕ĂŶĚϰϲϬŵĐĨ͘>ĂLJĚŽǁŶŐƵŶƐ͕ĂůůƐŚŽƚƐ ĨŝƌĞĚ͕ŐƵŶǁĂƐǁĞƚ͘DhϭϰΖĂŶĚϱΖϮͲϳͬϴΗ,ŐƵŶƐ͘ƌŵĂŶĚZ/,͘WƵůůĐŽƌƌĞůĂƚŝŽŶůŽŐ͕ƐĞŶĚƚŽƚŽǁŶ͕ŽŶĚĞƉƚŚ͘WĞƌĨŽƌĂƚĞ ƚŚĞĞůϮϴ>ĨƌŽŵϴ͕ϳϮϵΖͲϴ͕ϳϰϯΖ͘WĞƌĨŽƌĂƚĞƚŚĞĞůϮϴĨƌŽŵϴ͕ϲϵϴΖͲϴ͕ϳϬϯΖ͘WKK,͘>ĂLJĚŽǁŶŐƵŶƐ͕ĂůůƐŚŽƚƐĨŝƌĞĚ͕ŐƵŶǁĂƐ ǁĞƚ͘tĞůůŐĂŝŶĞĚϯͲϰƉƐŝŽĨ&dWĂŶĚΕϭϬϬŵĐĨĂĨƚĞƌƚŚĞƐĞůĂƐƚƚǁŽnjŽŶĞƐǁĞƌĞƉĞƌĨŽƌĂƚĞĚ͘^ĞĐƵƌĞƚƌĞĞ͘ZŝŐĚŽǁŶŵŽǀĞ ŽƵƚĨŽƌŶŽǁ͘ŽŵƉůĞƚĞĚϯŽĨϲƌƵŶƐĨŽƌƚŚŝƐƉĞƌĨŽƌĂƚŝŽŶƉƌŽŐƌĂŵ͘ ĂŝůLJKƉĞƌĂƚŝŽŶƐ͗ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌLJ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ hͲϮϰ ϱϬͲϭϯϯͲϮϬϲϯϵͲϬϬͲϬϬ ϮϭϰͲϭϭϮ ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ ϱͬϮϯͬϮϮ ϲͬϭϲͬϮϮ ĂŝůLJKƉĞƌĂƚŝŽŶƐ͗ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌLJ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ hͲϮϰ ϱϬͲϭϯϯͲϮϬϲϯϵͲϬϬͲϬϬ ϮϭϰͲϭϭϮ ϬϲͬϭϲͬϮϬϮϮͲdŚƵƌƐĚĂLJ Z/'hWKDW> d ͕^^ D> W>dKK>^dZ/E' WZ ^^hZ d ^dtͬ/ ^ >dKϮϱϬϬη͘͘͘͘͘͘͘͘͘W^^ > <dKϳϬϬη͕KW E^t͕Z/,ΛϭϱϬ&WD ^ΛϭϬϬϮϬΖ͕W/<hWE^dZdϲϬ&WDW^^ ' ^W/EE ZD>&hEd/KE/E'͕WK^^/> Zz&ZKDWd͘dd DWddK> E ^W/EE ZtKZ</E'͘^dZd>K''/E'hWϲϬ&WD&ZKDϭϬϬϭϱΖ͖&/E/^, ϲϬ&WDhWW^^͘dKK>^D>&hEd/KE/E'͕ '/EdZKh> ^,KKd/E' dKK>^^zE ͕ '/EϵϬ&WDKtEW^^ ^dZdϵϬ&WDhWW^^ dKK>^D>&hEd/KE/E'͕ '/EdZKh> ^,KKd/E' dKK>^tKZ</E'͘^dZdϵϬ&WDhWW^^ ^dZdϭϮϬ&WDKtEW^^͖^dZdϭϮϬ&WDhWW^^ ^dZdϭϱϬ&WDKtEW^^ ^dZdϭϱϬ&WDhWW^^ ϭϱD/E^dd/KE^dKWΛϴϰϬϬΖ ϭϱD/E^dd/KE^dKWΛϵϭϬϬΖ ^dd/KE^dKWΛϭϬϬϬϴ͘ϱΖ͕dKK>D>&hEd/KE &d ZϯD/E͘ /^/KED dKh^ d, dt ,s &KZd,/^ ^dd/KE͖͘WKK, hDWhW͕>K^ ^tE> K&&͘ '/EZ/'KtE Z/'KtEKDW> d ͕> s >Kd/KE͕dZs >dK^,KW ͖ŶĂůLJƐŝƐƐŚŽǁƐϰϭйŐĂƐƉƌŽĚƵĐƚŝŽŶĨƌŽŵdLJŽŶĞŬĂŶĚϱϵй ĨƌŽŵďĞůƵŐĂ 6WDWH3URY $ODVND &RXQWU\ 86$ &RPLQJOHGSURGXFWLRQIRUP7\RQHNDQG %HOXJD3RROV3$ V3HU&2&WKH ZHOOQHHGVDSURGXFWLRQORJHYHU\ PRQWKV,QLWLDOORJREWDLQHG 1H[W3/ORJGXHE\ :HOO1DPH 1XPEHU %HDYHU&UHHN8QLW$ &RXQW\RU3DULVK .HQDL3HQLQVXOD%RURXJK /HDVH 5HYLVHG%\ 6FKHPDWLF5HYLVLRQ'DWH 'RQQD$PEUX] %&8 3DG )1/ ):/ 6HF715:60 7' 0' 79' 3HUPLW $3, 3URS'HV )('$ .%HOHYDWLRQ $*/ /DW 1 /RQJ : 6SXG KUV 7' KUV 5LJ5HOHDVHG KUV 3%7' 0' 79' ^, Dd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d/KE^͗ ŽŶĞDdsŵƚ^njĂƚĞ^ƚĂƚƵƐ >ϮϲϴϰϱϰͲϴϰϲϱϳϴϱϭͲϳϴϲϮϭϭϮͲϳͬϴΗϬϱͬϮϲͬϮϮKƉĞŶ >ϮϲϴϰϵϬͲϴϰϵϴϳϴϴϲͲϳϴϵϱϴϮͲϳͬϴΗϬϱͬϮϲͬϮϮKƉĞŶ >ϮϳϴϱϰϰͲϴϱϰϵϳϵϰϬͲϳϵϰϲϱϮͲϳͬϴΗϬϱͬϮϲͬϮϮKƉĞŶ >ϮϳϴϱϲϬͲϴϱϴϮϳϵϱϳͲϳϵϳϵϮϮϮͲϳͬϴΗϬϱͬϮϲͬϮϮKƉĞŶ >ϮϳϴϱϵϭͲϴϱϵϲϳϵϴϴͲϳϵϵϯϱϮͲϳͬϴΗϬϱͬϮϲͬϮϮKƉĞŶ >ϮϴϴϲϰϱͲϴϲϲϱϴϬϰϮͲϴϬϲϮϮϬϮͲϳͬϴΗϬϱͬϮϲͬϮϮKƉĞŶ >ϮϴϴϲϵϴͲϴϳϬϯϴϬϵϲͲϴϭϬϬϱϮͲϳͬϴΗϬϱͬϮϯͬϮϮKƉĞŶ >Ϯϴ>ϴϳϮϵͲϴϳϰϯϴϭϮϱͲϴϭϯϵϭϰϮͲϳͬϴΗϬϱͬϮϯͬϮϮKƉĞŶ >ϮϵϴϳϴϳͲϴϳϵϬϴϭϴϰͲϴϭϴϵϯϮͲϳͬϴΗϬϱͬϮϯͬϮϮKƉĞŶ >ϯϬϴϵϬϱͲϴϵϬϵϴϯϬϮͲϴϯϬϲϰϮͲϳͬϴΗϬϱͬϮϯͬϮϮKƉĞŶ >ϯϭϴϵϯϰͲϴϵϯϵϴϯϯϮͲϴϯϯϲϱϮͲϳͬϴΗϬϱͬϮϯͬϮϮKƉĞŶ >ϯϮϴϵϵϭͲϴϵϵϲϴϯϴϳͲϴϯϵϯϱϮͲϳͬϴΗϬϱͬϮϯͬϮϮKƉĞŶ dͲϭyϵϯϮϴͲϵϯϯϱϴϳϮϱͲϴϳϯϮϳϮͲϳͬϴΗϬϯͬϭϱͬϮϮKƉĞŶ dͲϭyϵϯϮϴͲϵϯϯϱϴϳϮϱͲϴϳϯϮϳϯͲϭͬϴΗϬϯͬϮϴͬϮϮKƉĞŶ dͲϯϵϴϰϬͲϵϰϴϰϴϴϳϳͲϴϴϴϭϰϰϯͲϭͬϴΗϬϰͬϬϭͬϮϮKƉĞŶ dͲϴϭϬϬϭϯͲϭϬϬϯϯϵϰϭϬͲϵϰϯϬϮϬϬϱͬϬϭͬϭϱKƉĞŶ dͲϴϭϬϬϭϯͲϭϬϬϯϯϵϰϭϬͲϵϰϯϬϮϬϯͲϭͬϴΗϬϯͬϮϴͬϮϮKƉĞŶ dͲϴ>ϭϬϬϳϭͲϭϬϬϴϰϵϰϲϴͲϵϰϴϭϭϯϮͲϳͬϴΗϬϯͬϭϰͬϮϮ/ƐŽůĂƚĞĚ dͲϭϱϭϬϲϲϴͲϭϬϲϳϮϭϬϬϱϰͲϭϬϬϱϵϰϮͲϳͬϴΗϬϯͬϭϯͬϮϮ/ƐŽůĂƚĞĚ dͲϭϵϭϬϵϲϬͲϭϬϵϳϬϭϬϯϱϳͲϭϬϯϲϳϭϬϯͲϭͬϴΗϬϮͬϭϲͬϭϴ/ƐŽůĂƚĞĚ dͲϮϬϭϭϭϳϬͲϭϭϭϴϬϭϬϱϲϳͲϭϬϱϳϳϭϬϯͲϭͬϴΗϭϭͬϭϲͬϭϰ/ƐŽůĂƚĞĚ 7\RQHN7 7\RQHN7 7DJ# 6/0 %OLQG%R[ 7 7/ 7 5$0NU-W55$ 0N -W 55 7; 7 %(/ %(/ %(/ %(/ %(/ %(/ %(/ Kaitlyn Barcelona Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 564-4422 Received By: Date: Date: 07/11/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL Well API # PTD # Log Date Log Company Log Type Notes BCU 18RD 50133205840100 222033 6/11/2022 Yellowjacket GPT-PERF + Report BCU 18RD 50133205840100 222033 6/18/2022 Yellowjacket GPT-PERF + Report BCU 18RD 50133205840100 222033 6/7/2022 Yellowjacket GPT-PLUG + Report BCU 24 50133206390000 214112 6/16/2022 Halliburton PPROF BCU 24 50133206390000 214112 5/23/2022 Yellowjacket GPT-PERF + Report BCU 24 50133206390000 214112 5/26/2022 Yellowjacket GPT-PERF + Report BCU 7A 50133202840100 214060 6/21/2022 Yellowjacket CBL BCU 7A 50133202840100 214060 6/15/2022 Yellowjacket GAMMA RAY + Report BRU 232-26 50283200770000 184138 5/25/2022 Yellowjacket CBL CLU 01RD 50133203230100 203129 5/19/2022 Yellowjacket PERF + Report CLU 01RD 50133203230100 203129 5/24/2022 Yellowjacket PERF + Report CLU 09 50133205440000 204161 5/27/2022 Yellowjacket PERF + Report CLU-1RD 50133203230100 203129 5/28/2022 Halliburton PPROF + Report END 1-17A 50029221000100 196199 5/26/2022 Halliburton LDL END 1-45 50029219910000 189124 5/23/2022 Halliburton LDL + Report END 3-17F 50029219460600 203216 6/15/2022 AK E-Line PLUG CUT FALLS CREEK 3 50133205240000 203102 6/4/2022 Yellowjacket PERF + Report HVB B-16 50231200400000 212133 6/14/2022 AK E-Line CIBP KALOTSA 1 50133206570000 216132 7/7/2022 Yellowjacket PERF + Report KBU 11-07 50133205560000 205165 6/16/2022 Yellowjacket GPT-PERF + Report KBU 11-07 50133205560000 205165 6/20/2022 Yellowjacket GPT-PERF + Report KBU 33-06X 50133205290000 203183 6/22/2022 Yellowjacket CBL MPU B-28 50029235660000 216027 5/27/2022 Halliburton LDL MPU B-28 50029235660000 216027 5/27/2022 Halliburton MFC + Report MPU B-30 50029235710000 216153 5/18/2022 Halliburton PERF MPU E-06 50029221540000 191048 5/28/2022 Halliburton MFC + Report Kaitlyn Barcelona Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 564-4422 Received By: Date: MPU E-35 50029236150000 218152 6/15/2022 Halliburton MFC + Report MPU L-50 50029235550000 215132 6/24/2022 Read COIL FLAG PAXTON 10 50133206910000 220064 5/27/2022 Halliburton PPROF + Report PBU C-24B 50029208160200 212063 5/28/2022 Halliburton PPROF + Report PBU C-24B 50029208160200 212063 5/28/2022 Halliburton RBT PBU GNI-03 50029228200000 197189 6/25/2022 Read CALIPER PBU GNI-03 50029228200000 197189 6/25/2022 Read TEMP-PRESS PBU K-01 50029209980000 183121 6/21/2022 Halliburton PPROF + Report PBU M-13A 50029205220100 201165 5/27/2022 Halliburton TMD3D-WFL + Report PBU NGI-05 50029201960000 176014 6/7/2022 Halliburton CAST PBU W-01A 50029218660100 203176 6/8/2022 Halliburton RBT SRU 241-33 50133206630000 217047 6/13/2022 Yellowjacket PERF SRU 241-33B 50133206960000 221053 5/25/2022 Halliburton TEMP-PRESS SRU 32A-33 50133101640100 191014 6/11/2022 AK E-Line PPROF Please include current contact information if different from above. BCU 18RD PTD:222-033 T36747 BCU 24 PTD:214-112 T36748 BCU 7A PTD:214-060 T36749 BRU 232-26 PTD:184-138 T36750 CLU 01RD PTD:203-129 T36751 CLU 09 PTD: 204-161 T36752 CLU1RD PTD:203-129 T36751 END 1-17A PTD:196-199 T36753 END 1-45 PTD:189-124 T36754 END 3-17F PTD:203-216 T36755 Falls Creek 3 PTD:203-102 T36756 HVB B-16 PTD:212-133 T36757 Kalosta 1 PTD:216-132 T36758 KBU 11-7 PTD:205-165 T36759 KBU 33-06X PTD:203-183 T36760 MPU B-28 PTD:216-027 T36761 MPU B-30 PTD:216-153 T36762 MPU E-06 PTD: 191-048 T36763 MPU E-35 PTD:218-152 T36764 MPU L-50 PTD:215-132 T36765 Paxton 10 PTD:220-064 T36766 PBU C-24B PTD:212-063 T36767 PBU GNI-03 PTD:197-189 T36768 PBU K-01 PTD:183-121 T36769 PBU M-13A PTD:201-165 T36770 PBU NGI-05 PTD:176-014 T36771 PBU W-01A PTD:203-176 T36772 SRU 241-33 PTD:217-047 T36773 SRU 241-33B PTD:221-053 T36774 SRU 32A-33 PTD: 191-014 T36775 Kayla Junke Digitally signed by Kayla Junke Date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aSVL 6HH6FKHPDWLF 3 W V )RUP5HYLVHG$SSURYHGDSSOLFDWLRQLVYDOLGIRUPRQWKVIURPWKHGDWHRIDSSURYDO By Meredith Guhl at 3:35 pm, Apr 14, 2022 'LJLWDOO\VLJQHGE\'DQ0DUORZH '1 FQ 'DQ0DUORZH RX 8VHUV 'DWH 'DQ0DUORZH %-0 ; '65 GWV -/& Jeremy Price Digitally signed by Jeremy Price Date: 2022.05.05 14:29:28 -08'00' RBDMS SJC 051122 tĞůů͗hͲϮϰ ĂƚĞ͗ϰͬϭϯͬϮϬϮϮ tĞůůEĂŵĞ͗hͲϮϰW/EƵŵďĞƌ͗ϱϬͲϭϯϯͲϮϬϲϯϵͲϬϬͲϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗KŶůŝŶĞ'ĂƐWƌŽĚƵĐĞƌWĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϮϭϰͲϭϭϮ ZĞŐƵůĂƚŽƌLJŽŶƚĂĐƚ͗ŽŶŶĂŵďƌƵnj;ϵϬϳͿϳϳϳͲϴϯϬϱ &ŝƌƐƚĂůů ŶŐŝŶĞĞƌ͗ZLJĂŶZƵƉĞƌƚ;ϵϬϳͿϳϳϳͲϴϱϬϯ;ϵϬϳͿϯϬϭͲϭϳϯϲ;Ϳ ^ĞĐŽŶĚĂůů ŶŐŝŶĞĞƌ͗:ĂŬĞ&ůŽƌĂ;ϵϬϳͿϳϳϳͲϴϰϰϮ;ϳϮϬͿϵϴϴͲϱϯϳϱ;Ϳ 0D[([SHFWHG%+3 aSVL# ¶79' SVLIWWRGHHSHVWRSHQSHUIV 0D[3RWHQWLDO6XUIDFH3UHVVXUH aSVL SVLIWWRVXUIDFH ƌŝĞĨtĞůů^ƵŵŵĂƌLJ hϮϰƌĞĐĞŶƚůLJŚĂƐŚĂĚdLJŽŶĞŬƉĞƌĨƐĂĚĚĞĚĂŶĚŚĂƐďƌŽƵŐŚƚƚŚĞƌĂƚĞƵƉĨƌŽŵΕϳϬϬŵĐĨĚƚŽΕϭϬϬϬŵĐĨĚ͘dŚĞƌĞ ĂƌĞĂĚĚŝƚŝŽŶĂůŐĂƐƐĂŶĚŽƉƉŽƌƚƵŶŝƚŝĞƐŝŶďŽƚŚƚŚĞĞůƵŐĂĂŶĚdLJŽŶĞŬWŽŽůƐͬW͛ƐŝŶƚŚŝƐǁĞůů͘KϮϯϳĂůůŽǁƐĨŽƌ ĐŽŵŝŶŐůŝŶŐŽĨƚŚĞĞůƵŐĂĂŶĚdLJŽŶĞŬŐĂƐƉŽŽůƐŝŶhϮϰ͘ dŚĞƉƵƌƉŽƐĞŽĨƚŚŝƐǁŽƌŬŝƐƚŽĂĚĚĂĚĚŝƚŝŽŶĂůƉĞƌĨƐƚŽhͲϮϰĨƌŽŵďŽƚŚƚŚĞĞůƵŐĂĂŶĚdLJŽŶĞŬƉŽŽůƐͬW͛Ɛ͘ EŽƚĞƐZĞŐĂƌĚŝŶŐtĞůůďŽƌĞŽŶĚŝƚŝŽŶ xϰͬϭͬϮϮ͗dͲϯƐĂŶĚƐŚŽƚǁŝƚŚĂϯͲϭͬϴ͟ŐƵŶdžϰ͛͘DĂĚĞŝƚĚŽǁŶƚŽϵϲϮϬ͛D;ŶŽƚĂŐͿ xϯͬϮϴͬϮϮ͗dͲϴĂŶĚdͲϭyƌĞƉĞƌĨ͛Ě͘ϯͲϭͬϴ͟džϮϬ͛ŐƵŶŵĂĚĞŝƚĚŽǁŶƚŽϭϬ͕Ϭϯϯ͛D;ŶŽƚĂŐͿ xϯͬϭϱͬϮϮ͗/WƐĞƚĂƚϭϬ͕Ϭϲϱ͛DĂŶĚϮϬ͛ĐĞŵĞŶƚĚƵŵƉďĂŝůĞĚŽŶƚŽƉďƌŝŶŐŝŶŐdŽƚŽϭϬ͕Ϭϰϱ͛D KϮϯϳĂůůŽǁƐĨŽƌ ĐŽŵŝŶŐůŝŶŐŽĨƚŚĞĞůƵŐĂĂŶĚ dLJŽŶĞŬŐĂƐƉŽŽůƐŝŶhϮϰ͘'/% tĞůů͗hͲϮϰ ĂƚĞ͗ϰͬϭϯͬϮϬϮϮ Ͳ>ŝŶĞWĞƌĨƉƌŽĐĞĚƵƌĞ ϭ͘D/Zh ͲůŝŶĞĂŶĚƉƌĞƐƐƵƌĞĐŽŶƚƌŽůĞƋƵŝƉŵĞŶƚ Ϯ͘WdůƵďƌŝĐĂƚŽƌƚŽϮϱϬƉƐŝůŽǁͬϯϱϬϬƉƐŝŚŝŐŚ ϯ͘Z/,ĂŶĚƉĞƌĨŽƌĂƚĞƐĂŶĚƐĨƌŽŵцϴ͕ϭϮϬ͛ʹцϵ͕ϭϱϮ͛D;цϳ͕ϱϬϳ͛ʹцϴ͕ϱϲϴ͛dsͿŝŶƚŚĞĞůƵŐĂWŽŽůƉĞƌ Z ͬ'ĞŽ ϰ͘Z/,ĂŶĚƉĞƌĨŽƌĂƚĞƐĂŶĚƐĨƌŽŵцϵ͕ϭϱϮ͛ʹцϭϬ͕Ϭϭϯ͛D;цϴ͕ϱϲϴ͛ʹцϵ͕ϰϭϬ͛dsͿŝŶƚŚĞdLJŽŶĞŬWŽŽůƉĞƌ Z ͬ'ĞŽ ϱ͘ZDK > ^>ͬ >WƌŽĚƵĐƚŝŽŶ>ŽŐŐŝŶŐƉƌŽĐĞĚƵƌĞ ϭ͘D/Zh^>Žƌ >ĂŶĚƉƌĞƐƐƵƌĞĐŽŶƚƌŽůĞƋƵŝƉŵĞŶƚ Ϯ͘WdůƵďƌŝĐĂƚŽƌƚŽϮϱϬƉƐŝůŽǁͬϯϱϬϬƉƐŝŚŝŐŚ ϯ͘KďƚĂŝŶƉƌŽĚƵĐƚŝŽŶůŽŐĂĐƌŽƐƐĞůƵŐĂĂŶĚdLJŽŶĞŬƉĞƌĨŽƌĂƚŝŽŶƐƚŽŽďƚĂŝŶƐƉůŝƚƐďĞƚǁĞĞŶƚŚĞƚǁŽƉŽŽůƐ Ă͘ŽŶƐƵůƚK ĨŽƌůŽŐŐŝŶŐƐƉĞĐŝĨŝĐƐ ď͘DƵƐƚďĞŽďƚĂŝŶĞĚǁŝƚŚŝŶϯϬĚĂLJƐĂĨƚĞƌŽďƚĂŝŶŝŶŐƐƚĂďŝůŝnjĞĚĨůŽǁƉĞƌKϮϯϳ Đ͘DƵƐƚďĞƐƵďŵŝƚƚĞĚƚŽK'ǁŝƚŚŝŶϯϬĚĂLJƐŽĨŽďƚĂŝŶŝŶŐůŽŐ ϰ͘ŽŶĨŝƌŵŐŽŽĚĚĂƚĂ͕ĂŶĚZDK^>ͬ >͘ ŽŶƚŝŶŐĞŶĐLJĂĚĚŝƚŝŽŶĂů >WůƵŐͬƉĂƚĐŚ;ƐͿ ϭ͘D/Zh ͲůŝŶĞĂŶĚƉƌĞƐƐƵƌĞĐŽŶƚƌŽůĞƋƵŝƉŵĞŶƚ Ϯ͘WdůƵďƌŝĐĂƚŽƌƚŽϮϱϬƉƐŝůŽǁͬϯϱϬϬƉƐŝŚŝŐŚ ϯ͘ZhEŝƚƌŽŐĞŶĂŶĚƉƵƐŚǁĂƚĞƌďĂĐŬŝŶƚŽĨŽƌŵĂƚŝŽŶ ϰ͘ŽŶĨŝƌŵǁĂƚĞƌůĞǀĞůŝƐďĞůŽǁŝŶƚĞƌǀĂůƚŽŝƐŽůĂƚĞ͕ĂŶĚƐĞƚϱͲϭͬϮ͟ƉůƵŐŽƌƉĂƚĐŚ͘ /Ĩ/W͕ŵƵƐƚďĞƐĞƚϱϬ͛ĂďŽǀĞƉĞƌĨ͕ĂŶĚŚĂǀĞϯϱ͛ĐĞŵĞŶƚĚƵŵƉďĂŝůĞĚƵŶůĞƐƐĂ>DǀĂƌŝĂŶĐĞŝƐŽďƚĂŝŶĞĚŝŶ ĂĚǀĂŶĐĞ /ĨĂůůŽĨƚŚĞdLJŽŶĞŬƉŽŽůͬWŝƐƐŚƵƚŽĨĨͬĂďĂŶĚŽŶĞĚ͕ŝƚǁŝůůŶĞĞĚĂ/WƐĞƚǁŝƚŚϱϬ͛ĐĞŵĞŶƚŽŶŝƚƉĞƌK' ϱ͘Z Ͳ>ŝŶĞhŶŝƚĂŶĚƚƵƌŶǁĞůůŽǀĞƌƚŽƉƌŽĚƵĐƚŝŽŶ͘ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ƵƌƌĞŶƚtĞůů^ĐŚĞŵĂƚŝĐ Ϯ͘WƌŽƉŽƐĞĚtĞůů^ĐŚĞŵĂƚŝĐ ϯ͘^ƚĂŶĚĂƌĚtĞůůƉƌŽĐĞĚƵƌĞʹEϮKƉĞƌĂƚŝŽŶƐ /ĨĂůůŽĨƚŚĞdLJŽŶĞŬƉŽŽůͬWŝƐƐŚƵƚŽĨĨͬĂďĂŶĚŽŶĞĚ͕ŝƚǁŝůůŶĞĞĚĂ/WƐĞƚǁŝƚŚϱϬ͛ĐĞŵĞŶƚŽŶŝƚƉĞƌK' 6WDWH3URY $ODVND &RXQWU\ 86$ :HOO1DPH 1XPEHU %HDYHU&UHHN8QLW$ &RXQW\RU3DULVK .HQDL3HQLQVXOD%RURXJK /HDVH 5HYLVHG%\ 6FKHPDWLF5HYLVLRQ'DWH 'RQQD$PEUX] %&8 3DG )1/ ):/ 6HF715:60 7' 0' 79' 3HUPLW $3, 3URS'HV )('$ .%HOHYDWLRQ $*/ /DW 1 /RQJ : 6SXG KUV 7' KUV 5LJ5HOHDVHG KUV 3%7' 0' 79' ^, Dd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d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ĞůƵŐĂϴ͕ϭϮϬ͛ʹ ϵ͕ϭϱϮ͛цϳ͕ϱϬϳΖʹ цϴ͕ϱϲϴ͛WƌŽƉŽƐĞĚd dLJŽŶĞŬ цϵ͕ϭϱϮ͛ʹ цϭϬ͕Ϭϭϯ͛цϴ͕ϱϲϴ͛ʹ цϵ͕ϰϭϬ͛WƌŽƉŽƐĞĚd 7\7; VSI2SHQ 7\7; VSI2SHQ 7\7 VSI2SHQ 7\7 2SHQ 7\7 VSI2SHQ 7\7/ VSI,VR 7\7 VSI,VR 7\7 VSI,VR 7\7 VSI,VR 7\RQHN7 7\RQHN7 7DJ# 6/0 %OLQG%R[ 7 7/ 7 5$0NU-W55$ 0N -W 55 7 7 7; 7 %HOXJD 7\RQHN ^dEZt >>WZK hZ E/dZK' EKW Zd/KE^ ϭϮͬϬϴͬϮϬϭϱ &/E>ǀϭ WĂŐĞϭŽĨϭ ϭ͘Ϳ D/ZhEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚĂŶĚ>ŝƋƵŝĚEŝƚƌŽŐĞŶdƌĂŶƐƉŽƌƚ͘ Ϯ͘Ϳ EŽƚŝĨLJWĂĚKƉĞƌĂƚŽƌŽĨƵƉĐŽŵŝŶŐEŝƚƌŽŐĞŶŽƉĞƌĂƚŝŽŶƐ͘ ϯ͘Ϳ WĞƌĨŽƌŵWƌĞͲ:Žď^ĂĨĞƚLJDĞĞƚŝŶŐ͘ZĞǀŝĞǁEŝƚƌŽŐĞŶǀĞŶĚŽƌƐƚĂŶĚĂƌĚŽƉĞƌĂƚŝŶŐƉƌŽĐĞĚƵƌĞƐĂŶĚ ĂƉƉƌŽƉƌŝĂƚĞ^ĂĨĞƚLJĂƚĂ^ŚĞĞƚƐ;ĨŽƌŵĞƌůLJD^^Ϳ͘ ϰ͘Ϳ ŽĐƵŵĞŶƚ ŚĂnjĂƌĚƐ ĂŶĚ ŵŝƚŝŐĂƚŝŽŶ ŵĞĂƐƵƌĞƐ ĂŶĚ ĐŽŶĨŝƌŵ ĨůŽǁ ƉĂƚŚƐ͘ /ŶĐůƵĚĞ ƌĞǀŝĞǁ ŽŶ ĂƐƉŚLJdžŝĂƚŝŽŶ ĐĂƵƐĞĚ ďLJ ŶŝƚƌŽŐĞŶĚŝƐƉůĂĐŝŶŐŽdžLJŐĞŶ͘DŝƚŝŐĂƚŝŽŶ ŵĞĂƐƵƌĞƐ ŝŶĐůƵĚĞĂƉƉƌŽƉƌŝĂƚĞ ƌŽƵƚŝŶŐŽĨĨůŽǁůŝŶĞƐ͕ĂĚĞƋƵĂƚĞǀĞŶƚŝŶŐĂŶĚĂƚŵŽƐƉŚĞƌŝĐŵŽŶŝƚŽƌŝŶŐ͘ ϱ͘Ϳ ^ƉŽƚWƵŵƉŝŶŐhŶŝƚĂŶĚdƌĂŶƐƉŽƌƚ͘ŽŶĨŝƌŵůŝƋƵŝĚEϮǀŽůƵŵĞƐŝŶƚƌĂŶƐƉŽƌƚ͘ ϲ͘Ϳ ZŝŐƵƉůŝŶĞƐĨƌŽŵƚŚĞEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚƚŽƚŚĞǁĞůůĂŶĚƌĞƚƵƌŶƐƚĂŶŬ͘^ĞĐƵƌĞůŝŶĞƐǁŝƚŚǁŚŝƉ ĐŚĞĐŬƐ͘ ϳ͘Ϳ WůĂĐĞ ƐŝŐŶƐ ĂŶĚ ƉůĂĐĂƌĚƐ ǁĂƌŶŝŶŐ ŽĨ ŚŝŐŚ ƉƌĞƐƐƵƌĞ ĂŶĚ ŶŝƚƌŽŐĞŶ ŽƉĞƌĂƚŝŽŶƐ Ăƚ ĂƌĞĂƐ ǁŚĞƌĞ EŝƚƌŽŐĞŶŵĂLJĂĐĐƵŵƵůĂƚĞŽƌďĞƌĞůĞĂƐĞĚ͘ ϴ͘Ϳ WůĂĐĞƉƌĞƐƐƵƌĞŐĂƵŐĞƐĚŽǁŶƐƚƌĞĂŵŽĨůŝƋƵŝĚĂŶĚŶŝƚƌŽŐĞŶƉƵŵƉƐƚŽĂĚĞƋƵĂƚĞůLJŵĞĂƐƵƌĞƚƵďŝŶŐ ĂŶĚĐĂƐŝŶŐƉƌĞƐƐƵƌĞƐ͘ ϵ͘Ϳ WůĂĐĞƉƌĞƐƐƵƌĞŐĂƵŐĞƐƵƉƐƚƌĞĂŵĂŶĚĚŽǁŶƐƚƌĞĂŵŽĨĂŶLJĐŚĞĐŬǀĂůǀĞƐ͘ ϭϬ͘Ϳ tĞůůƐŝƚĞDĂŶĂŐĞƌƐŚĂůůǁĂůŬĚŽǁŶǀĂůǀĞĂůŝŐŶŵĞŶƚƐĂŶĚĞŶƐƵƌĞǀĂůǀĞƉŽƐŝƚŝŽŶŝƐĐŽƌƌĞĐƚ͘ ϭϭ͘Ϳ ŶƐƵƌĞƉŽƌƚĂďůĞϰͲŐĂƐĚĞƚĞĐƚŝŽŶĞƋƵŝƉŵĞŶƚŝƐŽŶƐŝƚĞ͕ĐĂůŝďƌĂƚĞĚ͕ĂŶĚďƵŵƉƚĞƐƚĞĚƉƌŽƉĞƌůLJƚŽ ĚĞƚĞĐƚ> >ͬ,Ϯ^ͬKϮͬKϮůĞǀĞůƐ͘ ŶƐƵƌĞEŝƚƌŽŐĞŶǀĞŶĚŽƌŚĂƐĂǁŽƌŬŝŶŐĂŶĚĐĂůŝďƌĂƚĞĚĚĞƚĞĐƚŽƌĂƐ ǁĞůůƚŚĂƚŵĞĂƐƵƌĞƐKϮůĞǀĞůƐ͘ ϭϮ͘Ϳ WƌĞƐƐƵƌĞƚĞƐƚůŝŶĞƐƵƉƐƚƌĞĂŵŽĨǁĞůůƚŽĂƉƉƌŽǀĞĚƐƵŶĚƌLJƉƌĞƐƐƵƌĞŽƌDW^W;DĂdžŝŵƵŵWŽƚĞŶƚŝĂů ^ƵƌĨĂĐĞWƌĞƐƐƵƌĞͿ͕ǁŚŝĐŚĞǀĞƌŝƐŚŝŐŚĞƌ͘dĞƐƚůŝŶĞƐĚŽǁŶƐƚƌĞĂŵŽĨǁĞůů;ĨƌŽŵǁĞůůƚŽƌĞƚƵƌŶƐƚĂŶŬͿ ƚŽϭ͕ϱϬϬƉƐŝ͘WĞƌĨŽƌŵǀŝƐƵĂůŝŶƐƉĞĐƚŝŽŶĨŽƌĂŶLJůĞĂŬƐ͘ ϭϯ͘Ϳ ůĞĞĚŽĨĨƚĞƐƚƉƌĞƐƐƵƌĞĂŶĚƉƌĞƉĂƌĞĨŽƌƉƵŵƉŝŶŐŶŝƚƌŽŐĞŶ͘ ϭϰ͘Ϳ WƵŵƉŶŝƚƌŽŐĞŶĂƚĚĞƐŝƌĞĚƌĂƚĞ͕ŵŽŶŝƚŽƌŝŶŐƌĂƚĞ;^&DͿĂŶĚƉƌĞƐƐƵƌĞ;W^/Ϳ͘ůůŶŝƚƌŽŐĞŶƌĞƚƵƌŶƐ ĂƌĞƚŽďĞƌŽƵƚĞĚƚŽƚŚĞƌĞƚƵƌŶƐƚĂŶŬ͘ ϭϱ͘Ϳ tŚĞŶĨŝŶĂůŶŝƚƌŽŐĞŶǀŽůƵŵĞŚĂƐďĞĞŶĂĐŚŝĞǀĞĚ͕ŝƐŽůĂƚĞǁĞůůĨƌŽŵEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚĂŶĚ ďůĞĞĚĚŽǁŶůŝŶĞƐďĞƚǁĞĞŶǁĞůůĂŶĚEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚ͘ ϭϲ͘Ϳ KŶĐĞLJŽƵŚĂǀĞĐŽŶĨŝƌŵĞĚůŝŶĞƐĂƌĞďůĞĚĚŽǁŶ͕ŶŽƚƌĂƉƉĞĚƉƌĞƐƐƵƌĞĞdžŝƐƚƐ͕ĂŶĚŶŽŶŝƚƌŽŐĞŶŚĂƐ ĂĐĐƵŵƵůĂƚĞĚďĞŐŝŶƌŝŐĚŽǁŶŽĨůŝŶĞƐĨƌŽŵƚŚĞEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚ͘ ϭϳ͘Ϳ &ŝŶĂůŝnjĞũŽďůŽŐĂŶĚĚŝƐĐƵƐƐŽƉĞƌĂƚŝŽŶƐǁŝƚŚtĞůůƐŝƚĞDĂŶĂŐĞƌ͘ŽĐƵŵĞŶƚĂŶLJůĞƐƐŽŶƐůĞĂƌŶĞĚ ĂŶĚĐŽŶĨŝƌŵĨŝŶĂůƌĂƚĞƐͬƉƌĞƐƐƵƌĞͬǀŽůƵŵĞƐŽĨƚŚĞũŽďĂŶĚƌĞŵĂŝŶŝŶŐŶŝƚƌŽŐĞŶŝŶƚŚĞƚƌĂŶƐƉŽƌƚ͘ ϭϴ͘Ϳ ZDKEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚĂŶĚ>ŝƋƵŝĚEŝƚƌŽŐĞŶdƌĂŶƐƉŽƌƚ͘ Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 4/13/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 24 (PTD 214-112) Perf 3/28/2022 BCU 24 (PTD 214-112) Perf 4/01/2022 Please include current contact information if different from above. 214-112 T36471 Meredith Guhl Digitally signed by Meredith Guhl Date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y Samantha Carlisle at 9:02 am, Apr 06, 2022 'LJLWDOO\VLJQHGE\'DQ0DUORZH '1 FQ 'DQ0DUORZH RX 8VHUV 'DWH 'DQ0DUORZH ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ ϯͬϭϯͬϮϮ ϰͬϭͬϮϮ ϬϯͬϭϰͬϮϬϮϮͲDŽŶĚĂLJ tĞůůŚĂƐďĞĞŶŽŶůŝŶĞĚƵƌŝŶŐŶŝŐŚƚ͘^ŚƵƚǁĞůůŝŶ͘dƵďŝŶŐƉƌĞƐƐƵƌĞсϴϯƉƐŝ͘zĞůůŽǁ:ĂĐŬĞƚ ͲůŝŶĞĂƌƌŝǀĞŽŶůŽĐĂƚŝŽŶ͘ŽŶĚƵĐƚ :^ĂŶĚĂƉƉƌŽǀĞWdt͘ tĂƌŵƵƉĞƋƵŝƉŵĞŶƚ͘ WŝĐŬƵƉůƵďƌŝĐĂƚŽƌ͘Dh'WdǁŝƚŚϮͲϳͬϴΗdžϭϯΖƉĞƌĨŐƵŶ͘'Zͬ>ƚŽƚŽƉƐŚŽƚсϭϵ͘ϬΖ͘ DhůƵďƌŝĐĂƚŽƌƚŽǁŝƌĞůŝŶĞǀĂůǀĞƐŽŶƚƌĞĞ͘KƉĞŶǁĞůůĂŶĚZ/,͘&ŝŶĚĨůƵŝĚůĞǀĞůĂƚϵϰϮϬΖ͘dƵďŝŶŐƉƌĞƐƐƵƌĞсϮϯϬƉƐŝ͘ >ŽŐĐŽƌƌĞůĂƚŝŽŶƉĂƐƐĂŶĚƐĞŶĚƚŽZ ͬ' K͘^ŚŝĨƚĚŽǁŶϮΖ͘ >ŽŐŝŶƚŽƉŽƐŝƚŝŽŶǁŝƚŚ'Zͬ>ĂƚϭϬ͕ϬϱϮΖ͘WĞƌĨŽƌĂƚĞdͲϴ>njŽŶĞϭϬ͕ϬϳϭͲϭϬ͕ϬϴϰΖ͘ /ŶŝƚŝĂůWƌĞƐƐсϮϯϬƉƐŝ͘ ϱŵŝŶсϮϯϬƉƐŝ͘ ϭϬŵŝŶсϮϯϬƉƐŝ͘ ϭϱŵŝŶсϮϯϭƉƐŝ͘WKK,ǁŝƚŚƉĞƌĨŐƵŶ͘ ůůƐŚŽƚƐĨŝƌĞĚ͘'ƵŶŝƐǁĞƚ͘^ĂŶĚŝŶďƵůůƉůƵŐ͘ >ĂLJĚŽǁŶƚŽŽůƐƚƌŝŶŐĂŶĚůƵďƌŝĐĂƚŽƌ͘^ĞĐƵƌĞǁĞůůǁŝƚŚŶŝŐŚƚĐĂƉŽŶǁŝƌĞůŝŶĞǀĂůǀĞƐ͘ ^&E͘ ϬϯͬϭϯͬϮϬϮϮͲ^ƵŶĚĂLJ zĞůůŽǁ:ĂĐŬĞƚ ͲůŝŶĞŽŶůŽĐĂƚŝŽŶ͘ŽŶĚƵĐƚ:^ĂŶĚĂƉƉƌŽǀĞWdt͘ DhůƵďƌŝĐĂƚŽƌ͕ǁŝƌĞůŝŶĞǀĂůǀĞƐ͕ĂŶĚƉƵŵƉͲŝŶƐƵďǁŝƚŚƐĂŵƉůĞďĂŝůĞƌƚŽŽůƐƚƌŝŶŐ͘ tĂŝƚŽŶďůĞĞĚƚƌĂŝůĞƌƚŽďĞĞŵƉƚŝĞĚ͘ WƌĞƐƐƵƌĞdĞƐƚƚŽϮϱϬƉƐŝůŽǁͬϰϱϬϬƉƐŝŚŝŐŚ͘KƉĞŶǁĞůůĂŶĚZ/,͘dƵďŝŶŐƉƌĞƐƐƵƌĞсϯϬϬƉƐŝ͘ Z/,ƚŽϭϬ͕ϴϬϬΖǁŝƚŚƐĂŵƉůĞďĂŝůĞƌ͘WKK,͘ &ůƵŝĚƐĂŵƉůĞŝƐĐůĞĂƌǀŝƐĐŽƵƐĨůƵŝĚ͘ ŽůůĞĐƚĨůƵŝĚŝŶƐĂŵƉůĞďŽƚƚůĞ͘DhΘZ/,ǁŝƚŚϮͲϳͬϴΗdžϰΖƉĞƌĨŐƵŶ͘'Zͬ>ƚŽƚŽƉƐŚŽƚсϭϳ͘ϬΖ͘ ^ĞŶĚĐŽƌƌĞůĂƚŝŽŶůŽŐƚŽZ ͬ' K͘^ŚŝĨƚϭΖĚŽǁŶĂŶĚůŽŐŝŶƚŽƉŽƐŝƚŝŽŶ͘WĞƌĨŽƌĂƚĞdͲϭϱhnjŽŶĞϭϬ͕ϲϲϴͲϭϬ͕ϲϳϮΖ 'ŽŽĚŝŶĚŝĐĂƚŝŽŶŽĨŐƵŶĨŝƌŝŶŐĂƚƐƵƌĨĂĐĞ͘tĞŝŐŚƚůŽƐƐĂŶĚĐĂƉďƌĞĂŬ͘ /ŶŝƚŝĂůWƌĞƐƐƵƌĞсϯϭϯƉƐŝ͘ ϱŵŝŶсϯϭϯƉƐŝ͘ ϭϬŵŝŶсϯϭϯƉƐŝ͘ ϭϱŵŝŶсϯϭϯƉƐŝ͘WKK,͘'ƵŶŝƐǁĞƚ͘dŚŝĐŬŽŝůLJͬƐŽĂƉLJǁĂƚĞƌŝŶďƵůůƉůƵŐ͘ůůƐŚŽƚƐĨŝƌĞĚ͘ >ĂLJĚŽǁŶƚŽŽůƐƚƌŝŶŐ͘^ĞĐƵƌĞǁĞůůǁŝƚŚŶŝŐŚƚĐĂƉŽŶƚŽƉŽĨǁŝƌĞůŝŶĞǀĂůǀĞƐ͘ ,ĂŶĚŽǀĞƌǁĞůůƚŽŽƉƐ͘ƌŝŶŐǁĞůůŽŶůŝŶĞ͘ ĂŝůLJKƉĞƌĂƚŝŽŶƐ͗ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌLJ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ hͲϮϰ ϱϬͲϭϯϯͲϮϬϲϯϵͲϬϬͲϬϬ ϮϭϰͲϭϭϮ ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ ϯͬϭϯͬϮϮ ϰͬϭͬϮϮ ĂŝůLJKƉĞƌĂƚŝŽŶƐ͗ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌLJ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ hͲϮϰ ϱϬͲϭϯϯͲϮϬϲϯϵͲϬϬͲϬϬ ϮϭϰͲϭϭϮ ϬϯͬϮϴͬϮϬϮϮͲDŽŶĚĂLJ zĞůůŽǁũĂĐŬĞƚĐƌĞǁĂƌƌŝǀĞƐĂƚĨĂĐŝůŝƚLJĂŶĚŽďƚĂŝŶƐƉĞƌŵŝƚ͕W:^D͘ZŝŐƵƉĞůŝŶĞĞƋƵŝƉŵĞŶƚ͘tĞůůƐŚƵƚŝŶƐŝŶĐĞŵŝĚŶŝŐŚƚ͕^/dW ŝƐϭϭϬϬƉƐŝ͘WƌĞƐƐƵƌĞƚĞƐƚůƵďƌŝĐĂƚŽƌƚŽϮϱϬƉƐŝůŽǁͬϰϱϬϬƉƐŝŚŝŐŚ͘^ŚŽŽƚŝŶŐϯͲϭͬϴΗ'ĞŽĚLJŶĂŵŝĐƐ,ŐƵŶƐůŽĂĚĞĚĂƚϲ ^W&ǁŝƚŚϭϵŐĐŚĂƌŐĞƐ͘ƌŵĂŶĚZ/,ǁŝƚŚϮϬΖŐƵŶ͘ŽƌƌĞůĂƚĞƚŽŽƉĞŶŚŽůĞůŽŐĂŶĚƐĞŶĚƚŽƚŽǁŶĨŽƌĐŽƌƌĞĐƚŝŽŶ͘KŶĚĞƉƚŚ͕ ƉĞƌĨŽƌĂƚĞĚĨƌŽŵϭϬ͕ϬϭϯͲϭϬ͕ϬϯϯΖ͘/ŶŝƚŝĂů͗ϭϮϯϬƉƐŝ͘ϱŵŝŶ͗ϭϮϯϯƉƐŝ͘ϭϬŵŝŶ͗ϭϮϯϲƉƐŝ͘ϭϱŵŝŶ͗ϭϮϰϬƉƐŝ͘WKK,ĂŶĚůĂLJ ĚŽǁŶŐƵŶ͘ůůƐŚŽƚƐĨŝƌĞĚĂŶĚŐƵŶǁĂƐǁĞƚǁŝƚŚĂƐŵĂůůŵŽƵŶƚŽĨƐĂŶĚ͘ƌŵĂŶĚZ/,ǁŝƚŚϳΖŐƵŶ͘ŽƌƌĞůĂƚĞƚŽŽƉĞŶŚŽůĞ ůŽŐĂŶĚƐĞŶĚƚŽƚŽǁŶĨŽƌĐŽƌƌĞĐƚŝŽŶ͘ĚĚƚŚƌĞĞĨĞĞƚƐŚŝĨƚƉĞƌŐĞŽůŽŐŝƐƚŝŶƐƚƌƵĐƚŝŽŶĂŶĚƉĞƌĨŽƌĂƚĞdͲϭyĨƌŽŵϵϯϮϴͲϵϯϯϱΖ͘ /ŶŝƚŝĂů͗ϭϯϬϰƉƐŝ͘ϱŵŝŶ͗ϭϯϬϱƉƐŝ͘ϭϬŵŝŶ͗ϭϯϬϲƉƐŝ͘ϭϱŵŝŶ͗ϭϯϬϲƉƐŝ͘WKK,ĂŶĚůĂLJĚŽǁŶŐƵŶ͘ůůƐŚŽƚƐĨŝƌĞĚĂŶĚŐƵŶ ǁĂƐĚƌLJ͘^ĞĐƵƌĞǁĞůůĂŶĚZDKĞůŝŶĞ͘ ϬϯͬϭϱͬϮϬϮϮͲdƵĞƐĚĂLJ tĞůůǁĂƐƐŚƵƚͲŝŶƚŚŝƐŵŽƌŶŝŶŐ͘ zĞůůŽǁũĂĐŬĞƚŽŶůŽĐĂƚŝŽŶ͘W:^DĂŶĚƐŝŐŶƉĞƌŵŝƚ͘ tĂƌŵƵƉĞƋƵŝƉŵĞŶƚ ŚĞĐŬĨŝƌĞ͘Dh'WdĂŶĚϱͲϭͬϮΗ/W͘>ƚŽ/WϮϮ͘ϱΖ͘ ^ƚĂďďĞĚŽŶƚŽƚŚĞǁĞůů͘t,WϭϱϬƉƐŝ͘KƉĞŶǁĞůůĂŶĚZ/,͘&ŝŶĚĨůƵŝĚůĞǀĞůĂƚΕϴϴϳϬΖ͘^ĞŶĚůŽŐƚŽƚŽǁŶ͘ WƵůůĐŽƌƌĞůĂƚŝŽŶůŽŐĨŽƌ/W͘^ĞŶƚƚŽƚŽǁŶ͕ƐŚŝĨƚϯΖĚŽǁŶ͘ ^Ğƚ/WĂƚϭϬ͕ϬϲϱΖ͘'ŽŽĚŝŶĚŝĐĂƚŝŽŶŽĨƐĞƚ͘WKK,͘ ůŽƐĞǁĞůů͘>ĂLJĚŽǁŶ'WdĂŶĚƐĞƚƚŝŶŐƚŽŽů͘DhĐĞŵĞŶƚĚƵŵƉďĂŝůĞƌͲϭϵ͘ϭŐĂůůŽŶƐŽĨĐĞŵĞŶƚ͘ Z/,͘ ƵŵƉďĂŝůĐĞŵĞŶƚŽŶƚŽƉŽĨ/W͘dKĂƚϭϬ͕ϬϰϱΖ͘ WKK,͘ >ĂLJĚŽǁŶĐĞŵĞŶƚďĂŝůĞƌ͘ŚĞĐŬĨŝƌĞ͘DhϳΖϮͲϳͬϴΗŐƵŶ͘ Z/,͘WƵůůĐŽƌƌĞůĂƚŝŽŶůŽŐĨƌŽŵϵϰϴϬΖƚŽϵϭϯϬΖ͘^ĞŶĚƚŽƚŽǁŶ͕ƐŚŝĨƚůŽŐϯΖĚŽǁŶ͘ ^ŚŽŽƚƚŚĞdͲϭyĨƌŽŵϵ͕ϯϮϴΖƚŽϵ͕ϯϯϱΖ͘'ŽŽĚŝŶĚŝĐĂƚŝŽŶŽĨĨŝƌĞ͘ WKK,͘ WƌĞƐƐƵƌĞĚĂƚĂĂĨƚĞƌƐŚŽŽƚŝŶŐ͗ /ŶŝƚŝĂůͲϭϵϴƉƐŝ͘ ϱŵŝŶͲϯϬϰƉƐŝ͘ ϭϬŵŝŶͲϯϴϭƉƐŝ͘ ϭϱŵŝŶͲϰϱϮƉƐŝ͘ůŽƐĞƐǁĂď͘>ĂLJĚŽǁŶŐƵŶƐ͘'ƵŶǁĂƐĚƌLJ͘ƵůůƉůƵŐŚĂĚĚƌLJƐĂŶĚŝŶŝƚ͘ ZŝŐĚŽǁŶůƵďƌŝĐĂƚŽƌĂŶĚǁŝƌĞůŝŶĞǀĂůǀĞƐ͘ dƌĞĞĐĂƉŝŶƐƚĂůůĞĚ͘ KƉĞƌĂƚŽƌŽŶůŽĐĂƚŝŽŶƚŽĨůŽǁǁĞůů͘ zĞůůŽǁũĂĐŬĞƚZDK͘ ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ ϯͬϭϯͬϮϮ ϰͬϭͬϮϮ ĂŝůLJKƉĞƌĂƚŝŽŶƐ͗ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌLJ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ hͲϮϰ ϱϬͲϭϯϯͲϮϬϲϯϵͲϬϬͲϬϬ ϮϭϰͲϭϭϮ zĞůůŽǁũĂĐŬĞƚĂƌƌŝǀĞŽŶůŽĐĂƚŝŽŶĂŶĚƐŝŐŶƉĞƌŵŝƚ͘W:^D͘ dĞƐƚĨŝƌĞ͘DhϰΖϯͲϭͬϴΗϲƐƉĨĐŚĂƌŐĞƐ͘ϮϬΖ>ƚŽƚŽƉƐŚŽƚ͘ tĞůůǁĂƐƐŚƵƚŝŶΛϳDĂŶĚt,WŝƐĐƵƌƌĞŶƚůLJϲϬϬƉƐŝ͘ ^ƚĂďŽŶǁĞůůĂŶĚWdůƵďƌŝĐĂƚŽƌƚŽϮϱϬƉƐŝͬϰϱϬϬƉƐŝ͘ Z/,ĂŶĚƉƵůůĐŽƌƌĞůĂƚŝŽŶůŽŐĨƌŽŵϵ͕ϲϮϬΖƚŽϵ͕ϯϱϬΖ͘ ^ĞŶĚƚŽƚŽǁŶ͕ŵĂĚĞĂͲϭΖĐŽƌƌĞĐƚŝŽŶ͘^ŚŽŽƚƚŚĞdͲϯĨƌŽŵϵ͕ϰϴϬΖƚŽϵ͕ϰϴϰΖ͘WKK,͘ WƌĞƐƐƵƌĞĚĂƚĂ͗/ŶŝƚŝĂůͲϳϯϬƉƐŝ͕ϱŵŝŶͲϴϰϰƉƐŝ͕ϭϬŵŝŶͲϵϯϭƉƐŝ͕ϭϱŵŝŶͲϵϵϵƉƐŝ͘ >ĂLJĚŽǁŶŐƵŶƐ͘ůůƐŚŽƚƐĨŝƌĞĚ͘ƵůůƉůƵŐǁĂƐĨƵůůŽĨƐĂŶĚ͘'ƵŶǁĂƐĚƌLJ͘ >ĂLJĚŽǁŶůƵďƌŝĐĂƚŽƌ͘^ĞĐƵƌĞǁĞůůĂŶĚƚƵƌŶŽǀĞƌƚŽKƉƐ͘ ZDK͘ ϬϰͬϬϭͬϮϬϮϮͲ&ƌŝĚĂLJ 6WDWH3URY $ODVND &RXQWU\ 86$ :HOO1DPH 1XPEHU %HDYHU&UHHN8QLW$ &RXQW\RU3DULVK .HQDL3HQLQVXOD%RURXJK /HDVH 5HYLVHG%\ 6FKHPDWLF5HYLVLRQ'DWH 'RQQD$PEUX] %&8 3DG )1/ ):/ 6HF715:60 7' 0' 79' 3HUPLW $3, 3URS'HV )('$ .%HOHYDWLRQ $*/ /DW 1 /RQJ : 6SXG KUV 7' KUV 5LJ5HOHDVHG KUV 3%7' 0' 79' ^, Dd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his email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Chad Helgeson; Roby, David S (OGC) Cc:Donna Ambruz Subject:RE: Beaver Creek #24 (PTD#214-112) Sundry # 322-108 Date:Tuesday, March 22, 2022 1:57:00 PM Chad, You have approval to reperforate from 10,013-10,033’ under the existing sundry #322-108. You do not need additional approval to reperforate the T-1X sand from 9300-9340’ since it was already approved in this sundry. You can shoot it as many times as you like under Sundry 322-108. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Tuesday, March 22, 2022 1:53 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov> Cc: Donna Ambruz <dambruz@hilcorp.com> Subject: Beaver Creek #24 (PTD#214-112) Sundry # 322-108 Bryan/Dave, Last week we started perforating new Tyonek sands in Beaver creek #24. The first 2 sands we perforated T-15 and T-8L were wet and not exciting, so we set a plug over them and moved uphole to the T-1X sand where we saw a good sign of gas from the zone, however it appears we may have damaged the existing open sand T8 (10,013-10,033). We did not request permission to reperforate this sand and I was wondering if you could verbally approved the reperf of the existing open sand from 10,013-10,033 with this email? We may also reperf the T-1X sand that is approved, but do we need additional approval to shoot one sand 2 times in the same sundry? Thanks Chad Helgeson KEN Operations Engineer Hilcorp Alaska LLC chelgeson@hilcorp.com 907-777-8405 (O) 907-229-4824 (C) The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 3/24/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 24 (PTD 214-112) Plug/Perf/GPT 3/13/2022 Please include current contact information if different from above. 214-112 T36430 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.03.29 09:51:20 -08'00' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED By Samantha Carlisle at 2:29 pm, Mar 03, 2022 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate 0 Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development Q Stratigraphic ❑ Service ❑ 214-112 3. Address: 6. API Number: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 50-133-20639-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 237B Will planned perforations require a spacing exception? Yes El No ❑� Beaver Creek Unit (BCU) 24 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028083 I Beaver Creek / Beluga Gas, Tyonek Gas Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): 10,900; Junk (MD): 11,300' 10,697' 10,900' 10,297' - 3,427 psi 11,122' & 11,130' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 70' 16" 70' 70' Surface 3,187' 9-5/8" 3,187' 2,933' 5,750 psi 3,090 psi Intermediate Production 11,284' 5-1/2" 11,284' 10,681' 10,640 psi 7,460 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Swell Pkr: N/A 2,993' MD / 2,762' TVD; N/A 12. Attachments: Proposal Summary 1,j I Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑✓ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: March 17, 2022 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑� WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: AOGCC Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Digitally signed by Dan Marlowe Contact Name: Chad Helgeson, Operations Engineer Dan Marlowe (1267) Authorized Name and DN: cn=Dan Marlowe (1267), 267 Digital Signature with Date: Date 2022.03.0314:24:34-09'60• Contact Email: chelgeson(a)hilcorp.com Contact Phone: 907-777-8405 Authorized Title: Dan Marlowe, Operations Manager, 907-283-1329 AOGCC USE ONLY Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: 322-108 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Pressure test a -line lubricator to 5000 psi. Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No [ Subsequent Form Required: 10-404 Jeremy Digitally signed by Y Jeremy Price APPROVED BY 3/10/22 Approved b Price Date::280222.03.10 pp Y� 1a:2a:oz-oe'oo' COMMISSIONER THE AOGCC Date: Comm.dts Comm.JLC 3/10/2022 Isr Pet EngBJM 3/9/22 1 1 Sr Pet Geo DLB 03/04/2022 1 JSr Res Eng DSR-3/4/22 Form 10-403 Revised 10/2021 Approved application is valid for 12 months from the date of approval. RBDMS SJC 031122 Hilcoru Alaska, LL Well Prognosis Well: BCU-24 Date:3/2/2022 Well Name: BCU-24 API Number: 50-133-20639-00-00 Current Status: Flowing Leg: NA Estimated Start Date: 3/17/22 Rig: NA Reg. Approval Req'd? 10-403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-112 First Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (M) Second Call Engineer: Jake Flora (907) 777-8442 (0) (720) 988-5375 (M) AFE Number: Max. Expected BHP: — 4,435 psi @ 10,081' TVD (Based upon 0.44 psi/ft gradient) Max. Potential Surface Pressure: — 3,427 psi (Based on 0.1 psi/ft to surface) Brief Well Summary Beaver Creek Unit #24 was drilled as a Grass roots monobore completion in 2014 to target gas sands in the Sterling, Lower Beluga, and Tyonek formations. The initial zone perforated in the Tyonek in mid -November was non -productive. This zone was plugged back and the next Tyonek interval (T-18) was perforated. This zone produced gas before hydrates began to form. The hydrates were treated with a capillary string, but the well eventually loaded up with fluid and has been unable to produce with the fluid level very near to surface. It is suspected that the bridge plug set between the T-20 and T-18 zones was leaking and contributing to the formation water loading up in the well. A bridge plug was set and effectively isolated the water from the T-20. The T-3 zone was re -perforated in May 2015 to reduce skin damage. The purpose of this sundry is to add additional Tyonek perforations. Notes Regarding Wellbore Condition: Current flowrate: 700 mcf @ 90 psi Procedure: 1. MIRU E-line and pressure control equipment 2. PT lubricator above MASP Pressure test lubricator to 5000 psi. bjm 3. Rig up perf guns (3-1/8" 6 spf) 4. RIH and perforate the sand listed in the table below, per Geo/RE Sand Perf Zone Top (MD) Zone Bottom Zone Footage Order (MD) (MD) T-1X 3 ±9,300' ±9,340' 40' T3 3 ±9,445' ±9,495' 50' T5 4 ±9,605' ±9620' 15' T713 4 ±9,906' ±9,946' 40' T8L 2 ±101065' ±10,090' 35' T15U & L 1 ±101655' ±10,698' 43' Expected Perf Footage 7' 4' 3' 6' 13' 10, Well will be shot following the listed perf order. The next zone perf schedule will depend the results of the previous zone. (See contingency plug procedure below if water or sand is produced.) Hilcoru Alaska, LL Well Prognosis Well: BCU-24 Date:3/2/2022 For each perforating run make correlation pass and send log in to Operations Engineer, Reservoir Engineer and the Geologist. a. Use Gamma/CCL to correlate on the final signed perf sheet. b. Record initial and 5/10/15 minute tubing pressures after firing c. Consult with RE/Geo (Meredyth Richards/Sarah Frey) between each perf interval d. Above perfs will be shot in the Beaver Creek Tyonek Gas Pool 5. RD E-Line Unit and turn well over to production. E-line Plug Procedure (Contingency to Isolate Wet Sands) If any zone produces sand and/or water or needs isolated: 1. MIRU E-Line and pressure control equipment. PT lubricator above MASP PT to 5000 psi. bjm 2. RIH and set plug above the wet perforations a. Dump 35' of cement on any plug set 3. RIH and set patch as needed over zones making water, with production from below Attachments: 1. Actual Schematic 2. Proposed Schematic Hileorp Alaska, LLG #: 214-112 50-133-20639-00 les: FED A-028083 ✓ation: 179.2' (18.6' AGL) N60° 39' 30.871" W 151 ° 1' 2.842" 9/22/2014 16:00 hrs 10/09/2014 06:00 hrs eased: 10/16/2014 16:00 hrs Tree cxn = 9-1/2" Otis 8.0" Seal Diameter 5-1/8" Modified ID Bore TOC (CBL 10/30/14) - 2,584' BCU - 24 Pad 3 1,127 FNL, 1,645' FWL, Sec.34, T7N, R10W, S.M. r Capillary Tubina (Removed 2/02/15) 3/8" OD 2205 0.049" Stainless Steel Wall Thickness Two Bottom MD 0' 0' i TVD 0' 0' Jewelry 1. Swell Packer (21' Long) 2. CIBP (Capped w/ 35' cement 02/16/18) 3. CIBP (w/ 36' of cement 02/17/15) 4. CIBP (Set 11118114; Possibly leaking) Tag @ 11,046' SLM (4/10/15) 4.60" Blind Box N r 1 Depth 2,993' 10,900, Tyonek T8 11,122' 11,130' Tyonek T19 — Tyonek T20 RA Mkr Jt 5,799' SCHEMATIC Conductor 16" X-56 109 ppf To Bottom MD 0' 70' TVD 0' 70' Surface Casing 9-5/8" L-80 40 ppf BTC Ton Bottom MD 0' 3,187' TVD 0' 2,933' 12-1/4" hole Lead Cmt w/ 525 sks (230 bbls) of 12.0 ppg, Class G, Tail Cmt w/ 230 sks (50 bbls) of 15.4 ppg, Class G, 180 sks (78 bbls) to surface Production Casing 5-1/2" P-110 17 ppf CDC Top Bottom MD 0' 11,284' TVD 0' 10,681' 8-1/2" hole Cmt w/ 1,945sks ( 471 bbls) of 15.3 ppg, Class G cmt w/ EASYBLOK RA Mkr Jt 7,948' Casing/Cementing Detail 10.4 ppg Mud RA Mkr Jt 8,172' - 11.5 ppg Mud Push (35 bbl) 15.3 ppg Cement (471 bbl) nl - 8.5 ppg 3 % KCI (255 bbi) RA Mkr Jt 8,624' Perforations: Zone MD TVD Size SPF Date Status RA Mkr Jt 8,934' Tyonek T8 10,013-10,033' 9,410'-9,430' 3-1/8" 6 05/01/15 Open Tyonek T19 10,960'-10,970' 10,357'-10,367 3-1/8" 6 02/16/18 Iso Tyonek T2011,170'-11,180'10,56T-10,577' 3-1/8" 6 11/16/14 Iso 4 RA Mkr Jt 9,825' RA Mkr Jt 10,837' tMy fi 2 RA Mkr Jt 11,102' 3 4 Casing Shoe @ 11,284' TD: PBTD: 11,300' MD 10,900' MD 10,697' TVD 10,297' TVD Max Dogleg: 6.59°/100' @ 1,034' Max Inclination: 29.4° @ 2,826' Well Name & Number: Beaver Creek Unit #24 Lease: I A-028083 County or Parish: Kenai Peninsula Borough State/Prov: I Alaska Country: I USA Angle @KOP and Depth: 1.5° @ 500' Angle/Perfs: N/A Maximum Deviation: 29.4° @ 2,826' Date Completed: 11/16/2014 Ground Level (above MSL)71 160.6' 1 RKB (above GL): 18.6' Revised By: Donna Ambruz Downhole Revision Date: 1 5/1/2015 1 Schematic Revision Date: 2/21/2018 Hileorp Alaska, LLG #: 214-112 50-133-20639-00 les: FED A-028083 ✓ation: 179.2' (18.6' AGL) N60° 39' 30.871" W 151 ° 1' 2.842" 9/22/2014 16:00 hrs 10/09/2014 06:00 hrs eased: 10/16/2014 16:00 hrs Tree cxn = 9-1/2" Otis 8.0" Seal Diameter 5-1/8" Modified ID Bore TOC (CBL 10/30/14) - 2,584' Capillary Tubina (Removed 2/02/15) 3/8" OD 2205 0.049" Stainless Steel Wall Thickness TTo Bottom MD 0' 0' TVD 0' 0' Jewelry 1. Swell Packer (21' Long) 2. CIBP (Capped w/ 35' cement 02/16/18) 3. CIBP (w/ 36' of cement 02/17/15) 4. CIBP (Set 11118114; Possibly leaking) Tag @ 11,046' SLM (4/10/15) 4.60" Blind Box BCU - 24 Pad 3 1,127 FNL, 1,645' FWL, Sec.34, T7N, R10W, S.M. Depth • 2,993' 10,900, Tyonek T8 11,122' 11,130' ;f 1 Tyonek T19 RA Mkr Jt 5,799' RA Mkr Jt 7,948' PROPOSED SCHEMATIC Conductor 16" X-56 109 ppf To Bottom MD 0' 70' TVD 0' 70' Surface Casing 9-5/8" L-80 40 ppf BTC Ton Bottom MD 0' 3,187' TVD 0' 2,933' 12-1/4" hole Lead Cmt w/ 525 sks (230 bbls) of 12.0 ppg, Class G, Tail Cmt w/ 230 sks (50 bbls) of 15.4 ppg, Class G, 180 sks (78 bbls) to surface Production Casing 5-1/2" P-110 17 ppf CDC Top Bottom MD 0' 11,284' TVD 0' 10,681' 8-1/2" hole Cmt w/ 1,945sks ( 471 bbls) of 15.3 ppg, Class G cmt w/ EASYBLOK Casing/Cementing Detail 10.4 ppg Mud RA Mkr Jt 8,172' 11.5 ppg Mud Push (35 bbl) 15.3 ppg Cement (471 bbl) 8.5 ppg 3 % KCI (255 bbi) RA Mkr Jt 8,624' Perforations: Zone MD TVD Size SPF Date Status Tyonek 1X ±9,328'-9,335' ±8,725'-8,732' 3-1/8" 6 Proposed RA Mkr Jt 8,934' Tyonek T3 ±9,480'-9,484' ±8,877'-8,881' 3-1/8" 6 Proposed Tyonek T5 ±9,609'-9,612' ±9,006'-9,009' 3-1/8" 6 Proposed Tyonek T713 ±9,928'-9,934' ±9,325'-9,331' 3-1/8" 6 Proposed TyonekT8 10,013'-10,033' 9,410'-9,430' 3-1/8" 6 05/01/15 Open Tyonek T81- ±10,071'-10,084' ±9,468'-9,481' 3-1/8" 6 Proposed Tyonek T15 ±10,669'-10,672' ±10,066'-10,069' 3-1/8" 6 Proposed RA Mkr Jt 9,825' Tyonek T 15L±10,680'-10,684' ±10,077'-10,081' 3-1/8" 6 Proposed Tyonek T19 10,960'-10,970' 10,357'-10,367 3-1/8" 6 02/16/18 Iso Tyonek T20 11,170'-11,180' 10,567'-10,577' 3-1/8" 6 11/16/14 Iso RA Mkr Jt 10,837' 2 RA Mkr Jt 11,102' 3 Tyonek T20 ,Y.AL^ Casing Shoe @ 11,284' TD: PBTD: 11,300' MD 10,900' MD 10,697' TVD 10,297' TVD Max Dogleg: 6.59°/100' @ 1,034' Max Inclination: 29.4° @ 2,826' Well Name & Number: Beaver Creek Unit #24 Lease: I A-028083 County or Parish: Kenai Peninsula Borough State/Prov: I Alaska Country: I USA Angle @KOP and Depth: 1.5° @ 500' Angle/Perfs: N/A Maximum Deviation: 29.4° @ 2,826' Date Completed: 11/16/2014 Ground Level (above MSL): 160.6' RKB (above GL): 18.6' Revised By: Chad Helgeson Downhole Revision Date: 5/1/2015 Schematic Revision Date: 3/1/2022 STATE OF ALASKA AL& OIL AND GAS CONSERVATION COMNOSION REPORT OF SUNDRY WELL OPERATIONS FEB 2 6 2018 1. Operations Abandon Li Plug Perforations Lj Fracture Stimulate Ll Pull Tubing H h o n Lj Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ srforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2. Operator Name: Hilcorp Alaska, LLC 4. Well Class Before Work: Development Q Stratigraphic ❑ Exploratory ❑ Service ❑ 5. Permit to Drill Number: 214-112 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-133-20639-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: A028083 Beaver Creek (BCU) 24 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Beaver Creek / Undef Tyonek Gas Pool 11. Present Well Condition Summary: 10,900; Total Depth measured 11,300 feet Plugs measured 11,222 & 11,130 feet true vertical 10,697 feet Junk measured N/A feet Effective Depth measured 10,900 feet Packer measured N/A feet true vertical 10,297 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 70' 16" 70' 70' Surface 3,187' 9-5/8" 3,187' 2,933' 5,750 psi 3,090 psi Intermediate Production 11,284' 5-1/2" 11,284' 10,681' 10,640 psi 7,460 psi Liner Perforation depth Measured depth See Attached Schematic SCAN.. . True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) N/A N/A N/A N/A Packers and SSSV (type, measured and true vertical depth) Swell Pkr; N/A 2,993' MD 2,762' TVD 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: 0 4514 31 450 673 Subsequent to operation: 0 4408 0 425 690 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations Exploratory❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas 2 WDSPL Printed and Electronic Fracture Stimulation Data ❑ IGSTOR ❑ 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: 318-049 Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer(a)hilcoro.com Authorized Signature: Date: Z Z b Contact Phone: 777-8420 Form 10-404 Revised 4/2017 19 4� ?r18 Submit Original Only Vo�, . Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date BCU-24 E-Line 50-133-20639-00 1 214-112 2/16/18 2/16/18 Daily Operations: 02/16/2018 - Friday Sign in, PTW and JSA. Tailgate meeting. Mobe to location. Rig up lubricator, PT to 250 psi low and 4,000 psi high. RIH w/ 4.24" OD CIBP, tie into OHL and tag obstruction at 10,937'. Call town and discussed. Spotted plug at 10,935' and set plug. Lost 232 Ibs of line tension when plug set. Waited 10 min and picked up 30' and went back down and tagged plug. Had 1,800 psi on tubing when plug was set. POOH. Everything looked good. MU 4" x 30' cement dump bailer and filled with 17 ppg cement (15 gals = 17.5'). Tag plug at 10,935', pick up 20' and dump bail cement on top of plug. POOH. Good dump. Fill bailer up again and RIH and dump another 17.5' of cement on plug (35' total). Est TOC 10,900' and cement in place at 1900 hrs. POOH. Good dump. TP - 1,925 psi. Rig down lubricator and turn well over to field. E 0 Hilcorp Alaska, I U: Permit #: 214-112 API #: 50-133-20639-00 Prop. Des: FED A-028083 KB elevation: 179.2' (18.6' AGL) Lat. N60° 39' 30.871" Long: W151° 1' 2.842" Spud: 9/22/2014 16:00 hrs TD: 10/09/2014 06:00 hrs Rig Released: 10/16/2014 16:00 hrs Tree cxn = 9-1/2" Otis 8.0" Seal Diameter 5-1/8" Modified ID Bore TOC (CBL 10/30/14) - 2,584' Capillary Tubina (Removed 2102115) 3/8" OD 2205 0.049" Stainless Steel Wall Thickness ToR Bottom MD 0' 0' TVD 0' 0' Jewelry Depth 1. Swell Packer (21' Long) 2,993' 2. CIBP (Capped w/ 35' cement 02/16/18) 10900' 3. CIBP (w/ 36' of cement 02/17/15) 11:122' 4. CIBP (Set 11/18/14; Possibly leaking) 11,130' Tag @ 11,046' SLM (4/10115) 4.60" Blind Box BCU - 24 Pad 3 1,127 FNL, 1,645' FWL, Sec.34, T7N, R10W, S.M. X: i 5s 3 Tyonek T3 Tyonek T18 Tyonek T20 RA MkrA 5,799' RA Mkr Jt 7,948' SCHEMATIC Conductor 16" X-56 109 ppf Top Bottom MD 0' 70' TVD 0' 70' Surface Casing 9-5/8" L-80 40 ppf BTC Tog Bottom M D 0' 3,187' TVD 0' 2,933' 12-1/4" hole Lead Cmt w/ 525 sks (230 bbls) of 12.0 ppg, Class G, Tail Cmt w/ 230 sks (50 bbls) of 15.4 ppg, Class G, 180 sks (78 bbls) to surface Production Casing 5-1/2" P-110 17 ppf CDC Top Bottom MD 0' 11,284' TVD 0' 10,681' 8-1/2" hole Cmt w/ 1,945sks (471 bbls) of 15.3 ppg, Class G cmt w/ EASYBLOK Casing/Cementing Detail - 10.4 ppg Mud RA Mkr Jt 8,172' - 11.5 ppg Mud Push (35 bbl) 15.3 ppg Cement (471 bbl) - 8.5 ppg 3% KCI (255 bbl) RA MkrA 8,624' Perforations: Zone MD TVD Size SPF Date Status RAMkrA8,934' TyonekT3 10,013'-10,033' 9,410'-9,430' 3-1/8" 6 05/01/150pen TyonekT1810,960'-10,970' 10,357'-10,367 3-1/8" 6 02/16/18 Iso TyonekT2011,170'-11,180'10,567'-10,577' 3-1/8" 6 11/16/14 Iso RA MkrJt 9,825' RA MkrA 10,837' RA MkrJt 11,102' 3 I Casing Shoe @ 11,284' TD, PBTD: 11,300' MD 10,900' MD 10,697' TVD 10,297' TVD Max Dogleg: 6.59°/100' @ 1,034' Max Inclination: 29.4° @ 2,826' Well Name & Number: Beaver Creek Unit #24 Lease: A - 028083 County or Parish: Kenai Peninsula Borough State/Prov: I Alaska Country: USA Angle @KOP and Depth: 1.5° @ 500' Angle/Perfs: NIA Maximum Deviation: 29.4° 2,826' Date Completed: 11/16/2014 Ground Level (above MSL): 160.6' RKB (above GL): 18.6' Revised By: Donna Ambruz Downhole Revision Date: 1 5/1/2015 Schematic Revision Date: 2/21/2018 Ati OF Tib • • \ I�j 7,v THE STATE Alaska Oil and Gas Fs�� A ofTT e Conservation Commission 333 West Seventh Avenue t GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 '.� Main: 907.279.1433 of ALAS�P Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager Hilcorp Alaska, LLC SCANNEV 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Beaver Creek Field, Tyonek Gas Pool, BCU 24 Permit to Drill Number: 214-112 Sundry Number: 318-049 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, /a4e.c.; Cathy P. Foerster Commisssioner DATED this /Z day of February, 2018. RBDM S U-- Fr` 3 ,.018 RECEIVED • • . FEB U6 8 STATE OF ALASKA P7.5 2 i Z/) E) ALASKA OIL AND GAS CONSERVATION COMMISSION A OG APPLICATION FOR SUNDRY APPROVALS t.' 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑✓ • Fracture Stimulate ❑ Repair Well 0 Operations shutdown 0 Suspend 0 Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska,LLC Exploratory El Development Q • 214-112 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic 0 Service ❑ 6.API Number: Anchorage Alaska 99503 50-133-20639-00 ' 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Beaver Creek(BCU)24 ' Will planned perforations require a spacing exception? Yes 0 No 2 9.Property Designation(Lease Number): 10. Field/Pool(s): A028083 " Beaver Creek/Tyonek Gas Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): 277,IQsPlugs(MD): Junk(MD): 11,300'• 10,697' • 11,225' 10,622' -3,348 psi IFIrf 11,122'&11,130' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 70' 16" 70' 70' Surface 3,187' 9-5/8" 3,187' 2,933' 5,750 psi 3,090 psi Intermediate Production 11,284' 5-1/2" 11,284' 10,681' 10,640 psi 7,460 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic N/A N/A N/A 1 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Swell Pkr: N/A 2,993'MD/2,762'TVD;N/A 12.Attachments: Proposal Summary ❑✓ Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory 0 Stratigraphic ❑ Development❑D Service ❑ 14. Estimated Date for 15.Well Status after proposed work: Commencing Operations: February 20,2018 OIL 0 WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑r • WAG 0 GSTOR ❑ SPLUG 0 Commission Representative: GINJ 0 Op Shutdown ❑ 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: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer(thilcorp.com Contact Phone: 777-8420 Authorized Signature: �' /der Date: 1..16a/I R. COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 No ❑ Spacing Exception Required? Yes ❑ No ❑/ Subsequent Form Required: /b . LI 01 RI3 D - L L-- FT > 3 rola F�� , APPROVED BY Approved by: ate*? P COMMISSIONER THE COMMISSION Date: .Z /2 -/ 8 2 s1r/E1 #% i R�1 R' Submit Form and Form 10-403 Revised 4/2017 Approved applicati i •�•iv'�J o fLtl� date of approval. tt hments ip Duplicate • • Well Prognosis Well: BCU-24 Hilcorp Alaska,LL Date: 2/06/2018 Well Name: BCU-24 API Number: 50-133-20639-00 Current Status: Shut-In Gas Well Leg: N/A Estimated Start Date: February 20th, 2018 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-112 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) AFE Number: Current Bottom Hole Pressure: — 3,720 psi @ 9,456' TVD (Based on Build Up 9/23/16) Maximum Expected BHP: — 3,720 psi @ 9,456' TVD (Based on Build Up 9/23/16) Max. Possible Surface Pressure: 3,,28 psi (Based on 2016 Build Up and 277 V�OSG gas gradient to surface (0.10psi/ft) 2nf.— Brief Well Summary Beaver Creek Unit#24 was drilled as a Grass roots monobore completion in 2014 to target gas sands in the Sterling, Lower Beluga, and Tyonek formations.The initial zone perforated in the Tyonek in mid-November was non-productive.This zone was plugged back and the next Tyonek interval (T-18)was perforated. The Tyonek T-3 was added in May 2015. A production log ran in January 2018 indicated that only water was coming from the lower T-18 perforations. The purpose of this work/sundry is to set a CIBP on E-line to isolate the T-18 perforations to eliminate the v water production from the well. Notes Regarding Wellbore Condition • Well is Currently flowing at 4.5 MMscfd at 600 psi. E-line Procedure: 1. MIRU E-line, PT lubricator to 4,000 psi Hi 250 Low. 1. PU 5-1/2" CIBP. RIH W/Same to (+/-) 10,950'. Set same. POOH. 2. PU Dump Bailer. RIH W/Cement and place 35' of Cement on top of 5-1/2" CIBP (TOC @ (+/-) 10,915'). . 4. RD E-line. 5. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic • . IIBCU - 24 Pad 3 SCHEMATIC 1,127 FNL, 1,645'FWL, Sec.34, T7N, R10W, S.M. Hilcorp Alaska,LLC Permit#: 214-112 t Conductor API#: 50-133-20639-00 " 16" p6 Top109 Bottom ppf � Prop.Des: FED A-028083 of MD 0' 70' KB elevation: 179.2' (18.6'AGL) r e , TVD 0' 70' Lat: N60° 39' 30.871" Long: W151° 1' 2.842" Spud: 9/22/2014 16:00 hrs ii Surface Casing TD: 10/09/2014 06:00 hrs s 9.5/8" L-80 40 ppf BTC Rig Released: 10/16/2014 16:00 hrs i. at T0' Bottom j9 ! MD 0' 3,187' "'L TVD 0' 2,933' ,, 1 12-1/4"hole Lead Cmt w/525 sks(230 bbls)of Tree cxn=9-1/2"Otis 12.0 ppg,Class G, Tail Cmt w/230 sks(50 bbls) 8.0"Seal Diametertiyyy���,,, of 15.4 ppg,Class G, 180 sks(78 bbls)to surface 5-1/8"Modified ID Bore Production Casing TOC(CBL 10/30/14)-2,584' Lam. 5-1/2" P-110 17 ppf CDC Top Bottom RA Mkr Jt 5,799' MD 0' 11,284' TVD 0' 10,681' Capillary Tubing (Removed 2/02/15) Ol1flic 8-1/2"hole Cmt w/1,945sks(471 bbls)of 15.3 ppg, 3/8"OD 2205 0.049" y r) Class G cmt w/EASYBLOK Stainless Steel Wall Thickness $t Top Bottom MD 0' 0' RA Mkr Jt 7,948' TVD 0' 0' 0. 0 Casino/Cementing Detail - 10.4 ppg Mud RA Mkr Jt 8,172' - 11.5 ppg Mud Push(35 bbl) - 15.3 ppg Cement(471 bbl) ;j - 8.5 ppg 3%KCI(255 bbl) f i r RA Mkr Jt 8,624' 4 RA Mkr Jt 8,934' t RA Mkr Jt 9,825' Jewelry Depth r 1.Swell Packer(21'Long) 2,993' 6 2.CIBP(w/36'of cement 02/17/15) 11,122' M. 3.CIBP(Set 11/18/14;Possibly leaking) 11,130' Tyonek T3 a. ` 12p,51 RA Mkr Jt 10,837' Perforations: Zone MD TVD Size SPF Date Status ;r( Tyonek T3 10,013-10,033' 9,410'-9,430' 3-1/8" 6 5/01/15 Open .° // . Tyonek T18 10,960'-10,970' 10,357'-10,367 3-1/8" 6 12/09/14 Open t. Tyonek T2011,170'-11,180'10,567'-10,577' 3-1/8" 6 11/16/14 Iso Tyonek 118 F�'L-�� 2 -r}rrri t , q -, Mkr Jt 11,102' Tag @ 11,046'SLM(4/10/15) _ 4.60"Blind Box �' .! b; 3 Tyonek T20 f-,. Max Shoe @ 11,284' Max Dogleg: 6.59°1100'@ 1,034' TD: PBTD: Max Inclination: 11,300'MD 11,225'MD 10,697'TVD 10,622'111/13 29.4°@ 2,826' Well Name&Number: Beaver Creek Unit#24 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country:JUSA Angle @KOP and Depth: 1.5°@ 500' Angle/Perfs:1 N/A Maximum Deviation 29.4°@ 2,826' Date Completed 11/16/2014 _ Ground Level(above MSL): 160.6' RKB(above GL):_ 18.6' Revised By Donna Ambruz Downhole Revision Date: 5/1/2015 Schematic Revision Date 2/6/2018 • • BCU - 24 PROPOSED Pad 3 SCHEMATIC 1,127 FNL, 1,645'FWL, Sec.34, T7N, R10W, S.M. Hilcorp Alaska,LLC t Conductor Permit#: 214-112 x k qty;; y 16" X-56 109 ppf API#: 50-133-20639-00 iptatat *T:.2 Bottom Prop.Des: FED A-028083 rol MD 0' 70' KB elevation: 179.2' (18.6'AGL) r"'t , ' ND 0' 70' Lat: N60° 39' 30.871" Long: W151° 1' 2.842" 1 Spud: 9/22/2014 16:00 hrs r Surface Casing 9-5/8" L-80 40 ppf BTC TD: 10/09/2014 06:00 hrs qt".°tTom Bottom Rio Released: 10/16/2014 16:00 hrs ,i MD 0' 3,187' ,,-, TVD 0' 2,933' 1 12-1/4"hole Lead Cmt w/525 sks(230 bbls)of Tree cxn=9-1/2"Otis 12.0 ppg,Class G, Tail Cmt w/230 sks(50 bbls) 8.0"Seal Diameter :Tt @ ' of 15.4 ppg,Class G, 180 sks(78 bbls)to surface 5-1/8"Modified ID Bore , t.:;. Production Casinq TOC(CBL 10/30/14)-2,584' iii PA 5-1/2" P-110 17 ppf CDC Top Bottom RA MkrJt 5,799' MD 0' 11,284' _. TVD 0' 10,681' Capillary Tubing (Removed 2/02/15) r +'!± 8-1/2"hole Cmt w/1,945sks(471 bbls)of 15.3 ppg, 3/8"DD 2205 0.049" 'r Class G cmtw/EASYBLOK Stainless Steel Wall Thickness A T� Bottom MD 0' 0' RA Mkr Jt 7,948' TVD 0' 0' t oCasinq/Cementing Detail 0 7 - 10.4 ppg Mud RA Mkr Jt 8,172' - 11.5 ppg Mud Push(35 bbl) - 15.3 ppg Cement(471 bbl) - 8.5 ppg 3%KCI(255 bbl) li31 Litti f 0 , RA MkrJt 8,624' 7." k III gi ill.RA MkrJt 8,934' ii RA MkrJt 9,825' Jewelry Depth 1. Swell Packer(21'Long) 2,993' IBP(Capped w/35'cement) ±10,950' Tyonek T3 2. CIBP(w/36'of cment 02/17/15) 11,122' }T 3. CIBP(Set 11/18/14;Possibly leaking) 11,130' y RA MkrJt 10,837 Perforations: Zone MD ND Size SPF Date Status Tyonek T3 10,013'-10,033' 9,410.-9,430' 3-1/8" 6 5/01/15 Open a, t Tyonek T18 10,960'-10,970' 10,357'-10,367 3-1/8" 6 12/09/14 Open ,L` 1A Tyonek T2011170'-11,180'10,56T-10,577' 3-1/8" 6 11/16/14 Iso Tyonek T18 m 2 -?err?'': , ',..- -• MkrJt 11,102' Tag @ 11,046'SLM(4/10/15) 4.60"Blind Box3 Tyonek 720_ Casing Shoe @ 11,284' Max Dogleg: �y; ' 6.59°/100'@ 1,034' TD: PBTD: Max Inclination: 11,300'MD 11,225'MD 10,697'ND 10,622'TVD 29.4°@ 2,826' Well Name&Number: Beaver Creek Unit#24 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country:]USA Angle @KOP and Depth: 1.5°@ 500' Angle/Perfs:l N/A Maximum Deviation: 29.4°@ 2,826' Date Completed: 11/16/2014 Ground Level(above MSL): 160.6' RKB(above GL): 18.6' Revised By: Donna Ambruz Downhole Revision Date: 5/1/2015 Schematic Revision Date: 2/6/2018 OF 77/ • • yw'I/7,'SA THE STATE Alaska Oil and Gas ofALASICCA Conservation Commission — 333 West Seventh Avenue Ili _ �' wM GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 SCANNED dAN 1 zim Re: Beaver Creek Field, Tyonek Gas Pool, BCU 24 Permit to Drill Number: 214-112 Sundry Number: 317-593 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 2-4- day of December, 2017. �3 n 'l • • RECEIVED STATE OF ALASKA 1 9 ALASKA OIL AND GAS CONSERVATION COMMISSION n 22,017 0 7 j l 7 APPLICATION FOR SUNDRY APPROVALS AOGGC 20 AAC 25.280 1.Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repair Well 0 Operations shutdown 0 Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program El Plug for Redrill 0 Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Install Capstring ❑✓ • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development Q• 214-112 ' 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-133-20639-00- J 7.If perforating: 8.Well Name and Number: Z/.('7 � rL' What Regulation or Conservation Order governs well spacing in this pool? N/A Beaver Creek(BCU)24 • Will planned perforations require a spacing exception? Yes IDNo ❑� 9.Property Designation(Lease Number): 10.Field/Pool(s): A028083 Beaver Creek/Tyonek Gas Pool . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,300' • 10,697' ' 11,225' 10,622' -2,773 psi 11,120' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 70' 16" 70' 70' Surface 3,187' 9-5/8" 3,187' 2,933' 5,750 psi 3,090 psi Intermediate Production 11,284' 5-1/2" 11,284' 10,681' 10,640 psi 7,460 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 'Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Swell Pkr:N/A 2,993'MD/2,762'TVD;N/A 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic 0 Development 2 • Service 0 14. Estimated Date for 15.Well Status after proposed work: CommencingOperations: January 2,2018 • OILWINJWDSPL p 0 0 0 Suspended 0 16.Verbal Approval: Date: GAS Q . WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ 0 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: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer@hilcoro.com et/ Contact Phone: 777-8420 Authorized Signature: i'4Date: I Z/1 F/(7 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: a In ' c ^ Plug Integrity EI BOP Test EI Mechanical Integrity Test ❑ CI /J,Location Clearance Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ :_ Spacing Exception Required? Yes ❑ No d Subsequent Form Required: j� ... L.1grgN ��� y APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: kZ \-4-q I l l 4( 1,.� ,l .zc -17QlGINAL N Form 10-403 Revised 4/2017 A roved application is valid for 12n hs from the date of approval. ttachments Duplicate \'L /� � r z.z(:/7 Well Prognosis Well: BCU-24 Hilcorp Alaska,LLQ Date: 12/18/2017 Well Name: BCU-24 API Number: 50-133-20639-00 Current Status: Acitve Gas Well Leg: N/A Estimated Start Date: January 2nd, 2018 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-112 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) AFE Number: Current Bottom Hole Pressure: —3,720 psi @ 9,463" TVD (Based on BHP 96hr buildup 9-20-16) Max. Potential Surface Pressure: —2,773 psi (Based on 0.1 psi/ft to surface) Brief Well Summary Beaver Creek Unit#24 was drilled as a Grass roots monobore completion in 2014 to target gas sands in the Sterling, Lower Beluga,and Tyonek formations.The initial zone perforated in the Tyonek in mid-November was non-productive.This zone was plugged back and the next Tyonek interval (T-18)was perforated.This zone produced gas before hydrates began to form.The hydrates were treated with a capillary string, but the well eventually loaded up with fluid and has been unable to produce with the fluid level very near to surface. It is suspected that the bridge plug set between the T-20 and T-18 zones was leaking and contributing to the formation water loading up in the well. A bridge plug was set and effectively isolated the water from the T-20. The T-3 zone was re-perforated in May 2015 to reduce skin damage. The purpose of this work/sundry is to install a capillary injection string to help unload water from the well. Procedure: 1. MIRU Cap String Truck, PT lubricator to 3,000 psi Hi 250 Low. ./ 2. PU 3/8" capillary string. RIH and set at+/- 10,000'. 3. Set spool of remaining line near well. 4. Rig down Cap String Truck. 5. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic 0 0 BCU - 24 ACTUAL Pad 3 1,127 FNL, 1,645'FWL, SCHEMATIC Sec.34, T7N, R10W, S.M. Hilcorp Alaska,LLC Permit#: 214-112 I - 14 C7Gnduct X-56 109 ppf API#: 50-133-20639-00 t� IsmBottom Prop.Des: FED A-028083 MD 0' 70' KB elevation: 179.2' (18.6'AGL) k!t ; TVD 0' 70' Lat: N60° 39' 30.871" " 1 Long: W151° 1' 2.842" i Spud: 9/22/2014 16:00 hrs ""R. Surface Casinq TD: 10/09/2014 06:00 hrs ,9 -5/8" L-80 40 ppf BTC Tom Bottom Rig Released: 10/16/2014 16:00 hrs i.:.` . MD 0' 3,187' '% 1 ND 0' 2,933' 1 12-1/4"hole Lead Cmt w/525 sks(230 bbls)of Tree cxn=9-1/2"Otis 12.0 ppg,Class G, Tail Cmt w/230 sks(50 bbls) 8.0"Seal Diameter .,, s of 15.4 ppg,Class G, 180 sks(78 bbls)to surface 5-1/8"Modified ID Bore 0, Production Casinq TOC(CBL 10/30/14)-2,584' I V 5-1/2" P-110 17 ppf CDC J Top Bottom RA MkrJt 5,799' MD 0' 11,284' 1 ND 0' 10,681' Capillary Tubing (Removed 2102/15) 8-1/2"hole Cmt w/1,945sks(471 bbls)of 15.3 ppg, i. 3/8"OD 2205 0.049" sM'+. Class G cmt w/EASYBLOK Stainless Steel Wall Thickness Top Bottom °* MD 0' 0' RA Mkr Jt 7,948' ND 0' 0' PW iy 0 .1 Casinq/Cementing Detail - 10.4 ppg Mud RA Mkr Jt 8,172' - 11.5 ppg Mud Push(35 bbl) 1 - 15.3 ppg Cement(471 bbl) - 8.5 ppg 3%KCI(255 bbl) i' S RA MkrJt 8,624' RA Mkr Jt 8,934' 1 1 RA MkrJt 9,825' Jewelry Depth 1.Swell Packer(21'Long) 2,993' 04 2.CIBP(Proposed,capped w/40'cement) 11,120' Tyonek T3 3.CIBP(Set 11/18/14;Possibly leaking) 11,130' 0 837' Perforations:Zone MD e RA MkrJt 10, TVD Size SPF Date Status Tyonek T3 10,013'-10,033' 9,410'-9,430' 3-1/8" 6 5/01/15 Open i 4' TyonekT18 10,960'-10,970' 10,357-10,367 3-1/8" 6 12/09/14 Open '`' s, TyonekT20 11,170'-11,180'10,567-10,577' 3-1/8" 6 11/16/14 Iso Tyonek T18 2 - _v.J. •. MkrJt 11,102' Tag @ 11,046'SLM(4/10/15) 3 4.60"Blind Box Tyonek 720 T',,.. ks.. Casing Shoe @ 11,284' Max Dogleg: t, _* : 6.59°/100'@ 1,034' TD: PBTD: Max Inclination: 11,300'MD 11,225'MD 10,697'ND 10,622'ND 29.4°@ 2,826' Well Name&Number: Beaver Creek Unit#24 Lease:_ A-028083 County or Parish: Kenai Peninsula Borough State/Prov Alaska Country:lUSA Angle @KOP and Depth: 1.5°@ 500' Angle/Perfs:I N/A Maximum Deviation: 29.4°@ 2,826' Date Completed: 11/16/2014 Ground Level(above MSL): 160.6' RKB(above GL) 18.6' Revised By: Stan Porhola Downhole Revision Date: 5/1/2015 Schematic Revision Date 6/1/2015 • • BCU - 24 PROPOSED Pad 3 1,127 FNL, 1,645'FWL, SCHEMATIC Sec.34, T7N, R10W, S.M. Hileorp Alaska.LLC Permit#: 214-112 Conductor API#: 50-133-20639-00 �* 16 Top-2100639 Prop.Des: FED A-028083 ::. ',....,, -";. MD 0' 70' KB elevation: 179.2' (18.6'AGL) TVD 0' 70' Lat: N60° 39' 30.871" Long: W151' 1' 2.842" • Spud: 9/22/2014 16:00 hrs Surface Casing TD: 10/09/2014 06:00 hrs 9-518" L 8o 40 ppf BTC RigReleased: 10/16/2014 16:00 hrs TO Bottom sa;, ,+' MD 0' 3,187 t ND 0' 2,933' 1 12-1/4"hole Lead Cmt w/525 sks(230 bbls)of Tree cxn=9-1/2"Otist. 12.0 ppg,Class G, Tail Cmt w/230 sks(50 bbls) 8.0"Seal Diameter a ( v, of 15.4 ppg,Class G, 180 sks(78 bbls)to surface 5-1/8"Modified ID Bore € , Ping TOC(CBL 10/30/14)-2,584' S d2ctionP 110 q 17 ppf CDC Top Bottom RA MkrJt 5,799' MD 0' 11,284' *t TVD 0' 10,681' Capillary Tubing (Removed 2/02/15) 8-1/2"hole Cmt w/1,945sks(471 bbls)of 15.3 ppg, 3/8^OD 2205 0.049" Class G cmt w/EASYBLOK Stainless Steel Wall Thickness ®, Tp Bottom MD 0' 0' ' RA MkrJt 7,948' ND 0' 0' y ,404 it F . x Casing/Cementing Detail 0 - 10.4 ppg Mud Ai RA MkrJt 8,172' - 11.5 ppg Mud Push(35 bbl) - 15.3 ppg Cement(471 bbl) X) C - 8.5 ppg 3%KCI(255 bbl) ir 0 s RA MkrJt 8,624' F: V !II X RA MkrJt 8,934' ri ,. Capillary String Proposed to Install r RA Mkr Jt 9,825' 3/8" 2205 Stainless Steel(11,500'spool) Jewelry Depth + Top Bottom 1.Swell Packer(21'Long) 2,993' 2.CIBP(Proposed,capped w/40'cement) 11,120' '' MD 0' ±10,000' 3.CIBP(Set 11/18/14;Possibly leaking) 11,130' Tyonek T3 5- TVD 0' ±9,397' il i% ili RA Mkr Jt 10,837 Perforations: Zone MD TVD Size SPF Date Status r- Tyonek T3 10,013'-10,033' 9,410'-9,430' 3-1/8" 6 5/01/15 Open T18 10,960'-10,970' 10,357'-10,367 3-1/8" 6 12/09/14 Open Tyonek T2011,170'-11,180'10,56T-10,577' 3-1/8" 6 11/16/14 Iso Tyonek T18" 1. 2 -r}r r ,'')'74.' ; z=:t' -A MkrJt 11.102' Tag @ 11,046'SLM(4/10/15) • 4.60"Blind Box 3 Tyonek T20 - ,. 9 Casi Shoe 11.284' Max Dogleg: ' '" @ 6.59°/100'@ 1,034' TD: PBTD: Max Inclination: 11,300'MD 11,225'MD 10,697'TVD 10,622'ND 29.4°@ 2,826' Well Name&Number Beaver Creek Unit#24 Lease A-028083 County or Parish Kenai Peninsula Borough State/Prov Alaska Country:IUSA Angle @KOP and Depth 1.5°@ 500' Angle/Perfs.I N/A Maximum Deviation 29.4°@ 2,826' Date Completed 11/16/2014 Ground Level(above MSL) 160.6' RKB(above GL): 18.6' Revised By. Donna Ambruz Downhole Revision Date. 5/1/2015 Schematic Revision Date 12/18/2017 • • v01' g*•Q\��\I�j.- . THE STATE Alaska Oil and Gas ti ;�1 OfLASKA Conservation Commission Mi '� 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 �° Main: 907.279.1433 OA, S�Q. Fax: 907.276.7542 "`""^" vvtrogcc.alaska.gov Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 SCANNED MAR 0 12017, Anchorage, AK 99503 Re: Beaver Creek Field, Tyonek Gas Pool, BCU 24 Permit to Drill Number: 214-112 Sundry Number: 316-540 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, j'etP/4tLe.AL _ Cathy . Foerster Chair DATED this dray of October, 2016. RBDMS (N MI 78 2016 • • 0RECEIVED STATE OF ALASKA OCT 19 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AO CC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations 0 - Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate Q ' Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. Re-perforate Q 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number: Exploratory ❑ Development Q. 214-112 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,Alaska 99503 50-133-20639-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 237B Beaver Creek(BCU)24 ' Will planned perforations require a spacing exception? Yes ❑ No ❑✓ 9.Property Designation(Lease Number): 10.Field/Pool(s): A) w• Y,i t. A028083 ' Beaver Creek/,idgriyonek Gas Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,300' • 10,697' • 11,225' ' 10,622' ' 2,773' 11,120' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 70' 16" 70' 70' Surface 3,187' 9-5/8" 3,187' 2,933' 5,750 psi 3,090 psi Intermediate Production 11,284' 5-1/2" 11,284' 10,681' 10,640 psi 7,460 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): N/A;N/A N/A;N/A 12.Attachments: Proposal Summary El Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development IA 'Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: November 2,2016 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS Q • WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Joe Kaiser-777-8393 Email jkaiser@hilcorp.com Printed Name Chad Helgeson Title Operations Manager Signature C Phone 907-777-8405 Date 1Q/lcf116 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Ile– S Ll o Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ A RBDMS (/ Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: 1C)-_4O' ��� z ��� koLzsitI. APPROVED BY Approved by: `� J ,' `'` — COMMISSIONER THE COMMISSION Date:to GRiaG4NAL � t"� 4 tG Submit nForm and Form 10-403 Revised 11/2015 72 months from the date of approval. � Attachments in Duplicate /041.,,-"'i /o, 19:r4- • • Well Prognosis Well: BCU-24 Hilcorp Alaska,LLC Date: 10/18/2016 Well Name: BCU-24 API Number: 50-133-20639-00 Current Status: Acitve Gas Well Leg: N/A Estimated Start Date: November 2nd, 2016 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-112 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) AFE Number: Current Bottom Hole Pressure: —3,720 psi @ 9,463" TVD (Based on BHP 96hr buildup 9-20-16) Max. Potential Surface Pressure: —2,773 psi (Based on 0.1 psi/ft to surface) Brief Well Summary Beaver Creek Unit#24 was drilled as a Grass roots monobore completion in 2014 to target gas sands in the Sterling, Lower Beluga, and Tyonek formations.The initial zone perforated in the Tyonek in mid-November was - non-productive.This zone was plugged back and the next Tyonek interval (T-18) was perforated.This zone produced gas before hydrates began to form.The hydrates were treated with a capillary string, but the well eventually loaded up with fluid and has been unable to produce with the fluid level very near to surface. It is suspected that the bridge plug set between the T-20 and T-18 zones was leaking and contributing to the formation water loading up in the well.A bridge plug was set and effectively isolated the water from the T-20. The T-3 zone was perforated in April 2015. A recent BHP buildup suggests skin formation, restricting flow through the perforations. The purpose of this work/sundry is add perforations and reperforate the Tyonek T3 Sands. - E-line Procedure: 1. MIRU E-line, PT lubricator to 4,000 psi Hi 250 Low. ✓ a. Tree connection is 9.5" OTIS. 2. RU 6 spf HC wireline guns. 3. RIH and perforate the following intervals: Zone Sands Top (MD) Btm (MD) SPF Tyonek T3 10,013' 10,088' 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 Correlation Log. d. Use Gamma/CCL/to correlate. e. Install Crystal gauges before perforating. Record tubing pressures before and after each perforating run. f. All perforations in table above are located in the Tyonek Gas Pool based on Conservation Order No. 723B. 4. RD E-line. 5. Turn well over to production. • • Well Prognosis Well: BCU-24 Hilcorp Alaska,LLC Date: 10/18/2016 E-line Procedure(Contingency): Note:The bottom 5'of the zone will be shot first and tested for water influx. If no water is present, then the remaining T-3 interval will be shot. If water influx is proven, then continue with the procedure below. 6. MIRU E-line, PT lubricator to 4,000 psi Hi 250 Low. 7. RIH and set 5-1/2" Plug at"'10,075'. RIH with dump bailer& dump bail 10' of cement on top of plug. Or 8. RIH and set 5-1/2" Casing Patch across lower 5' of perforation for water shut-off. Attachments: 1. Actual Schematic 2. Proposed Schematic • • BCU - 24 ACTUAL Pad 3 1,127 FNL, 1,645'FWL, SCHEMATIC Sec.34, T7N, R10W, S.M. Hilcorp Alaska.LLC Conductor Permit#: 214-112 16" X-56 109 ppf API#: 50-133-20639-00 {, Top Bottom Prop.Des: FED A-028083 MD 0' 70' KB elevation: 179.2' (18.6'AGL) TVD 0' 70' Lat: N60° 39' 30.871" Long: W151° 1' 2.842" Spud: 9/22/2014 16:00 hrs Surface Casing 9-5/8" L-ao 40 ppf BTC TD: 10/09/2014 06:00 hrs T_� Bottom Rio Released: 10/16/2014 16:00 hrs MD 0' 3,187' TVD 0' 2,933' , 1 12-1/4"hole Lead Cmt w/525 sks(230 bbls)of Tree cxn=9-1/2"Otis 12.0 ppg,Class G, Tail Cmt w/230 sks(50 bbls) 8.0"Seal Diameter of 15.4 ppg,Class G, 180 sks(78 bbls)to surface 5-1/8"Modified ID Bore r Production Casing TOC(CBL 10/30/14)-2,584' ____________________---- -11:0' 5-1/2" P-110 17 ppf CDC ITop Bottom RA MkrJt 5,799' MD 0' 11,284' TVD 0' 10,681' i. Capillary Tubing (Removed 2102115) 8-1/2"hole Cmt w/1,945sks(471 bbls)of 15.3 ppg, 318"OD 2205 0.049" Class G cmt w/EASYBLOK Stainless Steel Wall Thickness Top Bottom ° MD 0' 0' RA MkrJt 7,948' TVD 0' 0' =r ? Casing/Cementing Detail ii 10.4 ppg Mud RA MkrJt 8,172' - 11.5 ppg Mud Push(35 bbl) - 15.3 ppg Cement(471 bbl) ! - 8.5 ppg 3%KCI(255 bbl) ', RA MkrJt 8,624' IRA MkrJt 8,934' II A' RA Mkr Jt 9,825' Jewelry Depth 1.Swell Packer(21'Long) 2,993' - 2.CIBP(Proposed,capped w/40'cement) 11,120' Tyonek T3 3.CIBP(Set 11/18/14;Possibly leaking) 11,130' I RA MkrJt 10,837' Perforations: Zone MD ND Size SPF Date Status Tyonek T3 10,013'-10,033' 9,410'-9,430' 3-1/8" 6 5/01/15 Open ' Tyonek T18 10,960'-10,970' 10,357'-10,367 3-1/8" 6 12/09/14 Open Tyonek T2011,170'-11,180'10,567'-10,577' 3-1/8" 6 11/16/14 Iso Tyonek T18 _ 2 'f -• MkrJt 11,102' Tag @ 11,046'SLM(4/10/15) 3 4.60"Blind Box " .,. ' Tyonek T20 Casing Shoe @ 11,284' Max Dogleg: 6.59°/100'@ 1,034' TD: PBTD: 11,300'MD 11,225'MD Max Inclination: 10,697'ND 10,622'TVD 29.4°@ 2,826' Well Name&Number: Beaver Creek Unit#24 _ Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country:lUSA Angle @KOP and Depth: 1.5°@ 500' Angle/Perfs:l N/A Maximum Deviation:_ 29.4°@ 2,826' Date Completed: 11/16/2014 Ground Level(above MSL): 160.6' RKB(above GL): 18.6' Revised By: Stan Porhola Downhole Revision Date: 5/1/2015 Schematic Revision Date: 6/1/2015 0 0 Iti BCU - 24 PROPOSED Pad 3 1,127 FNL, 1,645'FWL, SCHEMATIC Sec.34, T7N, R10W, S.M. I lilcorp Alaska. 1.1i' Permit#: 214-112 Conductor 16" X-56 109 ppf API#: 50-133-20639-00 Top Bottom Prop.Des: FED A-028083 MD 0' 70' KB elevation: 179.2' (18.6'AGL) ND 0' 70' Lat: N60° 39' 30.871" Long: W151° 1' 2.842" Spud: 9/22/2014 16:00 hrs Surface Casing TD: 10/09/2014 06:00 hrs 9-5/8" L-80 40 ppf BTC lop Bottom Rig Released: 10/16/2014 16:00 hrs MD 0' 3,187' TVD 0' 2,933' .---' 1 12-1/4"hole Lead Cmt w/525 sks(230 bbls)of Tree cxn=9-1/2"Otis 12.0 ppg,Class G, Tail Cmt w/230 sks(50 bbls) 8.0"Seal Diameter of 15.4 ppg,Class G, 180 sks(78 bbls)to surface 5-1/8"Modified ID Bore Production Casing TOC(CBL 10/30/14)-2,584' 5-1/2" P-110 17 ppf CDC I RA Mkr Jt 5,799' MD Top Bottom11,284' TVD 0' 10,681' Capillary Tubing (Removed 2/02/15) 8-1/2"hole Cmt w/1,945sks(471 bbls)of 15.3 ppg, 3/8"OD 2205 0.049" Class G cmt w/EASYBLOK Stainless Steel Wall Thickness Top Bottom ' MD 0' 0' 'RA MkrJt 7,948' TVD 0' 0' Casing/Cementing Detail • - 10.4 ppg Mud RA Mkr Jt 8,172' - 11.5 ppg Mud Push(35 bbl) - 15.3 ppg Cement(471 bbl) • - 8.5 ppg 3%KCI(255 bbl) I '4 RA Mkr Jt 8,624' IRA Mkr Jt 8,934' • ' "RA Mkr Jt 9,825' Jewelry Depth 1.Swell Packer(21'Long) 2,993' 2.CIBP(Proposed,capped w/40'cement) 11,120' 3.CIBP(Set 11/18/14;Possibly leaking) 11,130' - - I ''RA Mkr Jt 10,837' Perforations: Zone MD TVD Size SPF Date Status • Tyonek T3 10,013'-10,033' 9,410'-9,430' 3-1/8" 6 5/01/15 Open Tyonek T3 10,013'-10,088' 9,410'-9,485' Proposed Tyonek T18 10,960'-10,970' 10,357'-10,367 3-1/8" 6 12/09/14 Open Tyonek T2011,170'-11,180'10,567'-10,577' 3-1/8" 6 11/16/14 Iso Tyonek T18= 2 t;tri.tl•►7 -• MkrJt 11,102' Tag @ 11,046'SLM(4/10/15) 3 4.60"Blind Box Tyonek T20 - Casing Shoe @ 11,284' Max Dogleg: 6.59°/100'@ 1,034' TD: PBTD: 11,300'MD 11,225'MD Max Inclination: 10,697'ND 10,622'ND 29.4°@ 2,826' Well Name&Number: Beaver Creek Unit#24 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country:IUSA Angle @KOP and Depth: 1.5°@ 500' Angle/Perfs:I N/A Maximum Deviation: 29.4°@ 2,826' Date Completed: 11/16/2014 Ground Level(above MSL): 160.6' RKB(above GL): 18.6' Revised By: J.Kaiser Downhole Revision Date: 5/1/2015 Schematic Revision Date: 10/18/2016 S ! Colombie, Jody J (DOA) From: Roby, David S (DOA) Sent: Thursday, May 19, 2016 2:28 PM To: Colombie, Jody J (DOA) Subject: FW: Beaver Creek 24 (BCU 24 - PTD 2141120) Condensate-production and measurement Should probably file this also. itAtdel Jt1N 1 62516 Dave Roby (907) 793-1232 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 Dave Roby at(907)793-1232 or dave.robv@alaska.gov. From: Larry Greenstein [mailto:lgreenstein@hilcorp.com] Sent: Thursday, May 19, 2016 2:19 PM To: Roby, David S (DOA); Regg, James B (DOA) Subject: RE: Beaver Creek 24 (BCU 24 - PTD 2141120) Condensate production and measurement Absolutely, will do, Dave. We are curious as to how much condensate it will produce also. Thank you for the review. Larry From: Roby, David S (DOA) [mailto:dave.robv@alaska.gov] Sent: Thursday, May 19, 2016 1:52 PM To: Larry Greenstein; Regg, James B (DOA) Subject: RE: Beaver Creek 24 (BCU 24 - PTD 2141120) Condensate production and measurement Larry, Looks good to us. Please provide copies of the testing done to establish the condensate yield. Regards, Dave Roby (907) 793-1232 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 Dave Roby at (907)793-1232 or dave.robv@alaska.aov. From: Larry Greenstein [mailto:Igreenstein@hilcorp.com] Sent: Thursday, May 19, 2016 9:37 AM To: Regg, James B (DOA); Roby, David S (DOA) Subject: Beaver Creek 24 (BCU 24 - PTD 2141120) Condensate production and measurement 1 • • Hello Jim and Dave, The BCU 24 well was perforated in the newly defined Tyonek Gas Pool and has provided a pleasant surprise with its robust production and some free flowing condensate. We've been working with BLM to figure a way to recover this small daily volume of condensate and sell it with the oil coming out of the two oil wells in the field (BCU 4 & 5RD). The measurement and proper allocations of the condensate and the other wells' oil for proper production reporting has been a challenge, but BLM has approved the attached plans for doing just that. The small volume of condensate production doesn't justify the installation of standalone separation vessels, LACT metering or a piping system to accommodate its measurement and processing. As approved by BLM and described in the attached allocation variance request, the plan is to quantify the condensate production rate twice a year (based on barrels of condensate per million cubic feet of gas production) and use this factor with the wells daily production to calculate a condensate volume for the BCU 24 well each month. The condensate volume calculated for BCU 24 will be reported as 'oil' on the 10-405 and deducted from the field LACT meter volume prior to allocating the oil production back to the two oil wells. Royalties will be paid on the total volume going through the LACT meter each month. Also attached is an accounting flow schematic showing the flow path of the condensate and water coming from BCU 24. The fluids will join the BCU 5RD flowline and commingle with BCU 4 production prior to final separation and LACT metering. Please let me know if you have any questions regarding our plans to get a small increase in sales oil coming from the Beaver Creek field. Larry 777-8322 2 • Colombie, Jody J (DOA) From: Roby, David S (DOA) Sent: Thursday, May 19, 2016 1:52 PM To: Colombie,Jody J (DOA) Cc: Link, Liz M (DOA) Subject: FW: Beaver Creek 24 (BCU 24 - PTD 2141120) Condensate production and measurement Attachments: BLM Condensate Variance Request 5-3-2016.pdf; COA_Beaver Creek Unit_004 Variance_Condensate Handling Ammended.pdf; Exhibit A - BCU Flow Schematic.pdf; BCU 24 BLM NOI Condensate Approved 5-11-16.pdf Jody, Please have a copy of this put in the metering section of the Beaver Creek field file. Thanks, Dave Roby (907) 793-1232 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 Dave Roby at(907)793-1232 or dave.robv@alaska.gov. From: Larry Greenstein [mailto:lgreenstein@hilcorp.com] Sent: Thursday, May 19, 2016 9:37 AM To: Regg, James B (DOA); Roby, David S (DOA) Subject: Beaver Creek 24 (BCU 24 - PTD 2141120) Condensate production and measurement Hello Jim and Dave, The BCU 24 well was perforated in the newly defined Tyonek Gas Pool and has provided a pleasant surprise with its robust production and some free flowing condensate. We've been working with BLM to figure a way to recover this small daily volume of condensate and sell it with the oil coming out of the two oil wells in the field (BCU 4 & 5RD). The measurement and proper allocations of the condensate and the other wells' oil for proper production reporting has been a challenge, but BLM has approved the attached plans for doing just that. The small volume of condensate production doesn't justify the installation of standalone separation vessels, LACT metering or a piping system to accommodate its measurement and processing. As approved by BLM and described in the attached allocation variance request, the plan is to quantify the condensate production rate twice a year(based on barrels of condensate per million cubic feet of gas production)and use this factor with the wells daily production to calculate a condensate volume for the BCU 24 well each month. The condensate volume calculated for BCU 24 will be reported as 'oil' on the 10-405 and deducted from the field LACT meter volume prior to allocating the oil production back to the two oil wells. Royalties will be paid on the total volume going through the LACT meter each month. Also attached is an accounting flow schematic showing the flow path of the condensate and water coming from BCU 24. The fluids will join the BCU 5RD flowline and commingle with BCU 4 production prior to final separation and LACT metering. 1 i • Please let me know if you have any questions regarding our plans to get a small increase in sales oil coming from the Beaver Creek field. La,ry 777-8322 2 • Hilcorp Alaska, LLC 3800 Centerpoint Drive Suite 1400 Anchorage,AK 99503 Phone: 907-777-9393 Fax: 907-777-8580 Jkaiser@hllcorp.com May 3rd, 2016 Wayne Svejnoha, Branch of Chief of Energy & Minerals Bureau of Land Management 222 West Seventh Avenue, #13 Anchorage, Alaska 99513-7504 RE: Variance request for the proper allocation of free flowing Gas Condensate from BCU-24 at the Beaver Creek Unit(AA50859) Mr. Svejnoha: Hilcorp Alaska, LLC (Hilcorp), as operator of the Beaver Creek Unit ("BCU") hereby requests the Bureau of Land Management authorize a variance from Onshore Order No. 4— Measurement of Oil for the allocation of free flowing condensate from Beaver Creek 24 at Beaver Creek Production Facility to maximize marketable condensate. Background Beaver Creek 24 was drilled in October 2014 and completed in December of 2014. This well is a high pressure gas well that initially had problems with hydrate forming down hole. The hydrates were problematic until May of 2015. Since this time,the well has produced an average of 9.5 MMscfd gas rate and about 30 bbl of water per day. Currently this well is producing 8.6 MMscfd and 27bb1/day of water. Recently, Hilcorp tested this well and determined that a percentage of the water has condensate of marketable value when mixed with Beaver Creek 4 & 5RD oil production. Due to the low volume of condensate, believed to be 1-3 bbl/day, we propose the following for proper condensate measurement and allocation. Allocation Variance Request Hilcorp requests to develop a "condensate production factor"(CPF) which correlates the barrels of condensate produced per 1.0 MMscfd gas rate in order to properly report the condensate volume produced and sold as oil. For example, if a well has a CPF of 0.13 and daily gas production of 10.0 MMscfd, then: (CPF)*(Daily Production)=Condensate Produced per day (0.13 barrels condensate/day/MMscfd) * (10.0 MMscfd) — 1.3 bbl/day condensate Hilcorp proposes to perform a test on a semi-annual basis to update and/or verify the CPF. This test will be done by producing the liquids from BCU 24 for a minimum of 72 • 410 BCU 24 Condensate Allocation Variance Page 2 of 4 hrs to an isolated tank. During this time, water production will be pumped off the bottom as required to maintain a safe liquid level in the tank. Following the time period the condensate pad layer will be strapped and volume calculated from condensate layer height. The condensate volume will be divided by the total gas production over the same time period to calculate the CPF. The CPF will be used to properly allocate the amount of condensate produced from the gas well. Condensate Collection: There is no need for further condensate processing equipment or additional collection tank at BCU. The gas condensate can be treated as oil and efficiently processed as such. In other locations around the United States, condensate may have a different value or may exceed the Reid Vapor pressure when mix with oil. As in this case at BCU, oil is the only marketable product in the local region and the reid vapor pressure will remain less than 12 psia per DOT requirements. Upon approval of this request, the condensate will be produced to the existing produced liquid tank T-202 on Pad 3. Please see attach Exhibit A—BCU Proposed Condensate/Oil now Schematic. This dramatically simplifies the process of condensate collection and is a similar process to the approved method of NGL handling at Swanson River Oil Field where NGLs from gas production is mixed in with the Oil prior to separation and sales. With a much lower density than produced liquids, the condensate will develop a pad layer in the T-202. When a sufficient pad layer is achieved, Operators will pump the condensate into the existing oil system, where it will be mixed with gross liquids from the BCU oil wells BCU 4 and BCU 5RD. After 3-phase separation, the oil/condensate will be directed to Tank 5, where it will remain until sold as sales quality crude. Conclusion With the approval from BLM, the methods outlined above, Hilcorp can to properly, safely, and accurately allocate condensate production to BCU 24 to maximize marketable product at Beaver Creek Produciton Facility. If you require additional information regarding this request, please contact the undersigned at 777-8393 (jkaiser@hilcorp.com). Sincerel -3'oe Kaiser, O erating Engineer HILCORP ALASKA, LLC • • BCU 24 Condensate Allocation Variance Page 3 of 4 SUPPORTING DOCUMENTATION C Exhibit A: Proposed BCU Condensate/Oil Flow Schematic • I3CU 24 Condensate Allocation Variance Page 4 of 4 EXHIBIT A 1 _•— U O i W6= Y! v a Wz Et Zo zo /�O ' U ZON aO I D O oO m wI OO .4 '- Q Q H ad 11_11 41110 / . limil CCI .3Lai OQ Y CIZ I I O _ 21 i _ ! II g Iqlt D u OU V kao I I ' 11111 88 I � Z a o A r X I aa9ena3s �I un all i A. ‘ g a c LI m I I O a g W 2c, Ul Ea 5 t W Wry I I lY tz qp 1 O S I w 8 0 ,.....__Y (JJJ..l O a { D (w N 0 0 w U I WO LI 1 ---1 T I,,1 G O z , V ' Owo UMF p_j 0 < O i � ZI Q i�ww w [3.<,s1 r, 3 (>10O0m >O O O r LL O •QY k O < I NLAal 74 . f< 4 I I J z c 'b ',owiO I- « ,�mw< ) I1 1MQ>-Q t >z- < w w z 0 0 I I w C.) w a no w 0 w �Ows� ru w a w .wa- z 2 E ru as a y U 'w�o� a 3 f 2 0 a < z r • C+o w �L I z ��u c_� i � 0 0 0 20 0_ I J w i i z z a o , o (----t-s 4111 wZJ`= �� . ` w IQ v � o , .- < 2 000 g = Z• Q > $ WW W I z 3N X N W c0 •O L H I I LLI III *- w w Z z < y< w d LI c'Y= 0w WLLfI�IG F. z ww %~ w > ow ,z o,, L x P c,- Erz2Jw > (5 m a a N J s s w Q 2 2 o� O LL LL m U K Qp O M FE w LL , c_—„ L ( )1 n 8 mW L _ - _ i - - - - - � T 1 g • • . 1 b /dm Bureau of Land Management ' CONDITIONS OF APPROVAL °- FOR SUNDRY NOTICE—NOTICE OF INTENT A L,ot �: � Hilcorp Alaska, LLC.—Swanson River Unit ', Beaver Creek Unit- Onshore Order 4 Variance Condensate Measurement Project Specific Requirements 1. Condensate production factor(CPF) tests shall be completed at least semi-annually. 2. A summary of CPF test results shall be submitted to the Authorized Officer within 10 days of completion of testing via Sundry Notice, Subsequent Report. 3. During CPF tests the API gravity of the condensate shall be determined. This API gravity shall be reported on monthly OGOR reports. 4. All condensate shall be reported to the appropriate Participating Area(s)on the monthly OGOR-C forms as code 02 and on OGOR-B forms as Code 10 (Produced Into Inventory). 5. In the event condensate production increases to greater than 10 bbls/day, the Authorized Officer must be notified before the next production reporting period ends. Notification Requirements: 1. All notifications and changes to the submitted Notice of Intent must be reported verbally or in writing to one of the following contacts listed below at the BLM Alaska State Office, Branch of Energy: Amanda Eagle Petroleum Engineer/Inspector 907-271-3266 Mutasim Elganzoory Petroleum Engineer 907 271-4224 After Hours Contact: Amanda Eagle 907-538-2300 dilliir G` 5ha /Up Amanda Eagle Date BLM, Petroleum E .4r ,.u,ded Form 0 • (Augustst 2 2000 ITED STATES 7) FORM APPROVED DEPAR ENT OF THE INTERIOR OMB NO. 1004-0135 BUREAU OF LAND MANAGEMENT Expires:July 31,2010 5. Lease Serial No. • SUNDRY NOTICES AND REPORTS ON WELLS AKA028083 Do not use this form for proposals to drill or to re-enter an 6. If Indian,Allottee or Tribe Name abandoned well. Use form 3160-3(APD)for such proposals. SUBMIT IN TRIPLICATE-Other instructions on reverse side. 7. If Unit or CA/Agreement,Name and/or No. 891008868X 1. Type of Well 8.Well Name and No. 0 Oil Well ®Gas Well 0 Other BEAVER CREEK 24 2. Name of Operator Contact: DONNA AMBRUZ 9. API Well No. HILCORP ALASKA LLC E-Mail:DAMBRUZ@HILCORP.COM 50-133-20639-00-S1 3a. Address 3b. Phone No.(include area code) 10. Field and Pool,or Exploratory 3800 CENTERPOINT DR SUITE 1400 Ph: 907-777-8305 BEAVER CREEK ANCHORAGE,AK 99503-5826 Fx: 907-777-8510 4. Location of Well (Footage,Sec., T.,R.,M.,or Survey Description) 11. County or Parish,and State Sec 34 T7N R1OW NENW 1127FNL 1645FWL KENAI COUNTY,AK 60.658007 N Lat, 151.019685 W Lon 12. CHECK APPROPRIATE BOX(ES)TO INDICATE NATURE OF NOTICE,REPORT,OR OTHER DATA TYPE OF SUBMISSION TYPE OF ACTION 0 Acidize 0 Deepen 0 Production(Start/Resume) 0 Water Shut-Off ®Notice of Intent ❑Alter Casing 0 Fracture Treat 0 Reclamation 0 Well Integrity ❑ Subsequent Report 0 Casing Repair 0 New Construction 0 Recomplete el Other ❑Final Abandonment Notice 0 Change Plans 0 Plug and Abandon 0 Temporarily Abandon Onshore Order Varia ce ❑Convert to Injection 0 Plug Back 0 Water Disposal 13. Describe Proposed or Completed Operation(clearly state all pertinent details,including estimated starting date of any proposed work and approximate duration thereof. If the proposal is to deepen directionally or recomplete horizontally,give subsurface locations and measured and true vertical depths of all pertinent markers and zones. Attach the Bond under which the work will be performed or provide the Bond No.on file with BLM/BIA. Required subsequent reports shall be filed within 30 days following completion of the involved operations. If the operation results in a multiple completion or recompletion in a new interval,a Form 3160-4 shall be filed once testing has been completed. Final Abandonment Notices shall be filed only after all requirements,including reclamation,have been completed,and the operator has determined that the site is ready for final inspection.) Item 4. Action: Other Sundry Notice-Allocation Variance Please see attached letter that requests condensate allocation variance for Beaver Creek well 24. Start date: May 18, 2016 14. I hereby certify that the foregoing is true and correct. Electronic Submission#338302 verified by the BLM Well Information System For HILCORP ALASKA LL C, sent to the Anchorage Committed to AFMSS for processing by SHARON YARAWSKY on 05/03/2016(16SLY0079SE) Name(Printed/Typed) JOE KAISER Title OPERATIONS ENGINEER Signature (Electronic Submission) Date 05/03/2016 THIS SPACE FOR FEDERAL OR STATE OFFICE USE A roved B Y W YN SVEJNOHA Tit1eBRANCH CHIEF Date 05/11/201 P� Conditions of approval,if any,arc attached. Approval of this notice does not warrant or certify that the applicant holds legal or equitable title to those rights in the subject lease which would entitle the applicant to conduct operations thereon. Office Anchorage Title 18 U.S.C.Section 1001 and Title 43 U.S.C.Section 1212,make it a crime for any person knowingly and willfully to make to any department or agency of the United States any false,fictitious or fraudulent statements or representations as to any matter within its jurisdiction. ** BLM REVISED** BLM REVISED**BLM REVISED** BLM REVISED** BLM REVISED** Colombie, Jody J (DOA) From: Roby, David S (DOA) Sent: Thursday, May 19, 2016 1:53 PM To: Colombie, Jody J (DOA) Cc: Link, Liz M (DOA) Subject: FW: Beaver Creek 24 (BCU 24 - PTD 2141120) Condensate production and measurement This one too. Dave Roby (907) 793-1232 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 Dave Roby at(907)793-1232 or dave.roby@alaska.gov. From: Larry Greenstein [mailto:lgreenstein@hilcorp.com] Sent: Thursday, May 19, 2016 11:08 AM To: Roby, David S (DOA); Regg, James B (DOA) Subject: RE: Beaver Creek 24 (BCU 24 - PTD 2141120) Condensate production and measurement Appreciate the quick request for info, Dave. At the current production rates we are talking about 1-2 bpd of condensate. In the variance request attachment in the original e-mail, the estimate was 1-3 bpd at the gas rates at that time (early May). We have not performed the stacked production to a tank measurement yet, the estimated volume comes from some marginal shakeouts of the water(like you'd do for water in an oil well). Don't believe we could rely on shakeouts to determine the condensate yield as it's a small percentage of the total fluids coming out of the well. We figured the best measurement technique for a small volume would be to stack up some production to collect enough condensate to get an accurate volume over a known quantity of gas production from the well...maybe collect 2-3 days worth, whatever it takes to get a good volume. Hope this explains it well enough. Please call if you'd like to discuss. Larry From: Roby, David S (DOA) [mailto:dave.roby(aalaska.gov] Sent: Thursday, May 19, 2016 10:45 AM To: Larry Greenstein; Regg, James B (DOA) Subject: RE: Beaver Creek 24 (BCU 24 - PTD 2141120) Condensate production and measurement Larry, How small of a daily volume of condensate are we talking about here? Has the well been tested already, and if so what's the condensate yield? Thanks, 1 • Dave Roby (9,07) 193-1232 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 Dave Roby at(907(793-1232 or dave.robv@alaska.gov. From: Larry Greenstein [mailto:lgreenstein@hilcorp.com] Sent: Thursday, May 19, 2016 9:37 AM To: Regg, James B (DOA); Roby, David S (DOA) Subject: Beaver Creek 24 (BCU 24 - PTD 2141120) Condensate production and measurement Hello Jim and Dave, The BCU 24 well was perforated in the newly defined Tyonek Gas Pool and has provided a pleasant surprise with its robust production and some free flowing condensate. We've been working with BLM to figure a way to recover this small daily volume of condensate and sell it with the oil coming out of the two oil wells in the field (BCU 4 & 5RD). The measurement and proper allocations of the condensate and the other wells' oil for proper production reporting has been a challenge, but BLM has approved the attached plans for doing just that. The small volume of condensate production doesn't justify the installation of standalone separation vessels, LACT metering or a piping system to accommodate its measurement and processing. As approved by BLM and described in the attached allocation variance request, the plan is to quantify the condensate production rate twice a year(based on barrels of condensate per million cubic feet of gas production) and use this factor with the wells daily production to calculate a condensate volume for the BCU 24 well each month. The condensate volume calculated for BCU 24 will be reported as `oil' on the 10-405 and deducted from the field LACT meter volume prior to allocating the oil production back to the two oil wells. Royalties will be paid on the total volume going through the LACT meter each month. Also attached is an accounting flow schematic showing the flow path of the condensate and water coming from BCU 24. The fluids will join the BCU 5RD flowline and commingle with BCU 4 production prior to final separation and LACT metering. Please let me know if you have any questions regarding our plans to get a small increase in sales oil coming from the Beaver Creek field. Larry 777-8322 2 •�OF T�� • • y0*\'1//7.-s. THE STATE Alaska Oil and Gas hof Conservation Commission ., ALASI��A � :triti �� 333 West Seventh Avenue l., GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Oji p. Main: 907.279.1433 AL Fax: 907.276.7542 www.aogcc.alaska.gov April 13, 2016 Mr. Chad A. Helgeson Operations Manager Hilcorp Alaska, LLC SCANNED MAY 1 9 201& P.O. Box 244027 Anchorage, AK 99503 Re: Closeout-Notice of Violation Docket Number: OTH-15-032 Failure to Protect V lye Systems weaver Creek 242.TD 2141120) Beaver Creek 25 (PTD 2141320) The Alaska Oil and Gas Conservation Commission (AOGCC) issued a notice of violation to Hilcorp Alaska, LLC dated November 25, 2015 for failing to protect the well safety valve systems to ensure reliable operation under the range of weather conditions expected at the well site. Hilcorp responded on December 14, 2015 with the requested information including the list of wells that do not have well houses or some suitable protection of the safety valve system components installed. Also provided was a description of corrective actions (to be) taken by Hilcorp. The AOGCC does not intend to pursue any further enforcement action regarding the two Beaver Creek wells noted above. Adequate protection from extreme cold temperatures remains a concern for the Hilcorp-operated wells that do not have well houses installed and will continue to be a focus of AOGCC safety valve system inspections during winter months. Sincerely, ae,, i0 .2„,,,,,z„ Cathy fy. Foerster Chair, Commissioner cc: Mr. David Wilkins (Hilcorp) • • Regg, James B (DOA) From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Tuesday, December 22, 2015 5:23 PM I VZ'I IL) To: Regg, James B (DOA) Cc: Bruce Hershberger;Joey Hensley; Pete Iverson; Christopher Walgenbach; Larry Greenstein Subject: Non Wellhouse SSV testing in cold weather Jim, As we discussed on the phone, below is a list of wells we have function tested the SVS in the last 2 days during colder temperatures. Some of these are the wells without wellhouses or any protection. We have ordered material for them, but to ensure we are in compliance we are testing them as the temperature or well conditions drop, to ensure they are functioning as designed. Kenai Gas Field @ 11 deg KBU 23-05, 32-08, KDU 10 Ninilchik @ 10 deg F GO-8 Happy Valley @ 13 deg F HV-2, HV-8, HV-9, HV 10, HV 13, HV 14 & HV-15 Swanson tested all rod pumps @ 6 deg F SCU 12A-04, 13-34, 31-8, 32-8, 33-33, and 41A-08 Beaver Creek at-1 deg F BC 7, BC14, BC23, BC24, BC25 Red pad #1 @ 15 degF These wells all tripped at the low pressure set point, showing no indication of any freezing on the sense line or in the air or hydraulics to the valve. If the temperature in the fields drop below Odeg we will function test all the wells SVS that do not have wellhouses again to ensure there is no freezing in the SVS. GO-2 now has a wellhouse on it with heat and lights, so it is now protected. Chad • • Hilcorp Alaska, LLC RECEIVED Post Office Box 244027 Anchorage,AK 99524-4027 DEC 14 2015 Suite 1000 terpoint Drive Anchorage,AK 99503 December 14, 2015 AOGCC Cathy P. Foerster Chair, Commissioner Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 Re: Docket No. OTH-15-032 Failure to Protect Safety Valve Systems Beaver Creek 24 (PTD 2141120) Beaver Creek 25 (PTD 2141320) Dear Chair Foerster: We respond to the AOGCC's request dated November 25, 2015, for a list of Hilcorp Alaska, LLC (Hilcorp Alaska) operated wells that do not have well houses or some other suitable protection of the safety valve system (SVS) components, with a timeline for resolution and the plan for retesting the SVS during cold temperatures and a written plan describing what has been or will be done in the future to prevent sense line freezing AOGCC Request: Provide "a written plan describing what has been or will be done in the future to prevent its reoccurrence at Hilcorp-operated fields in Alaska. Included in the requested response should be a list of Hilcorp-operated wells that do not have well houses or some other suitable protection of the safety valve system components, a timeline for resolution, and plans for retesting the safety valve systems to demonstrate the reliable operation during cold temperatures." Hilcorp Alaska Response: Beaver Creek 24 and 25. Immediately upon failure of the SVS function test on Beaver Creek 24 and 25 an indirect fired heater was installed on the SSVs and sensing lines, thawing any frozen fluids in the safety valve system. The following day heat trace and temporary insulation was installed on the 2 wells SVS. The SVS's were function tested to ensure the lines were not frozen and would properly function, and they passed a function test. Heat blankets were measured and ordered for these 2 wells on November 24th, the permanent insulating blankets are scheduled to arrive December 22nd Other Hilcorp Alaska Wells. We have reviewed all other Hilcorp Alaska-operated wells for suitable cold-weather protection of the SVS. Following this review, we determined the following: • Cathy P.Foerster Docket Number: OTH-15-032 December 14,2015 Page 2 of 4 • All Hilcorp Alaska-operated offshore wells on the platforms in Cook Inlet are protected from the environment and do not need any additional protection. • All Hilcorp Alaska-operated wells currently producing on the North Slope (311 total) have well houses and some form of heat (heater, heat trace, or a high flowing wellhead temp). • All Hilcorp Alaska-operated wells on the North Slope with the potential to be returned to production or injection have well houses on them. • Hilcorp Alaska operates 255 onshore producing wells in the Cook Inlet basin. The remainder of this response focuses on those wells. Cook Inlet Onshore Wells. Of the 255 onshore producing Cook Inlet wells, 73 wells do not have wellhouses. We show these wells in Attachment 1 with the following data: Field, PTD #, Wellbore Name, Status, Well type (Oil/Gas), and whether there is a wellhouse, heat trace, insulation blanket on SSV, or insulation blanket on sensing line, with the date of proposed completion, and any additional comments on the SVS protection. Twenty-four of the wells without wellhouses are oil wells in Swanson River. These wells have high wellhead temperatures (approx. 80° F) and have insulation blankets on the SVS. Hilcorp considers these SVS protected from weather. The other 49 wells that do not have wellhouses on them are gas producing wells or storage wells from several different fields. There are 20 wells in total on the Kenai Peninsula that do not have any protection on the SVS from the environment. Six of these wells are rod pump wells in Swanson River which have all passed no flow tests. The SVS on the rod pump wells have one pressure transmitter that shut down the motor in the event of low pressure. The other fourteen wells with no protection are gas wells located in the following fields: Happy Valley— 7, Kenai Gas Field— 3, Red Pad— 1, GO Pad—2, Ninilchik State Pad— 1. The other 29 wells without wellhouses have some sort of protection on the safety valve or the sensing lines as shown in Attachment 1. Insulation blankets will be installed on all safety valves and safety valve sensing lines to protect all the unprotected wells no later than January 31, 2016. We tested all of the unprotected wells during October and November in temperatures near 32° F. When the ambient temperature drops below 15° F, the SVS on the unprotected wells will be function tested to ensure there is no freezing in the system. If the temperature drops below 0° F, all wells without wellhouses on them will be function tested to ensure that the SVS functions properly without a wellhouse. If there are repeatable problems with the SVS below 0° F, other forms of protection will be evaluated to ensure compliance with 20 AAC 25.265. Should you have any additional questions, please contact Chad Helgeson (777-8405 or chelgeson@hilcorp.com) or Larry Greenstein(777-8322 or lgreenstein@hilcorp.com). • Cathy P.Foerster Docket Number: OTH-15-032 December 14,2015 Page 3 of 4 Sincerely, HILCORP ALASKA, LLC ;74,71/4 Chad A Helgeson Operations Manager Attachment 1 —List of Wells on Kenai Peninsula without wellhouses cc: Chet Starkel Larry Greenstein David S Wilkins John Barnes Luke Saugier • • Cathy P.Foerster Docket Number: OTH-15-032 December 14,2015 Page 4 of 4 Beaver Creek(BC 24 & 25)PTD# 2141120 & 2141320 Docket No. OTH-15-032 Hilcorp Alaska Response Attachment 1 List of Wells without Wellhouses 10 40 > > > E N N N E E ccco > OO > > v v v to N m E E c c c c c E EEEEEE y Y m m m .cu .1 Y « Y Y :: C m m m C C vlv, 76 .7o76 N N N N N N N N N -0 N N 00 00 rt V Y -O -0110 00 00 00 Op 00 00 c N N C C C C C 03 C c C C C C C C N .-I LVJ OO LVJ > > > > > > > > > C > > > > CCCPPP N = C N N N N Vt N N N N N C C C N N N N N N Vl N N N N N N N N N N Vt Vt N N N C ` ` C C C C C C C -S -2 � c c c c c c c C C C c c c c c c CCCCCC 0 0 QJ 01 x 0 0 0 0 0 0 j 'j j 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 r0 N UJ 0 0 0 OJ N N N N O) l] 9 N U/ O1 N U) Q) O) O) UJ 01 N U/ N W U) d) N UJ N N UJ U1 Y Y Y Y Y Y C C C Y Y Y Y Y Y Y Y ..Y ..., , -, -. ..m G m Y C OO UO O CR m Cm m C C C C C C C C C C C C C C C C Ccmmmto CO !LI m m m �m mmm m m mmmm C C C C m00m E °3 mOm mmmmmm - - - m@ m CO m CO 00 E = m _ _ Y Y co% C C c vs z z c = _ = C C C C C C N N C C C C C c C c C c C C C C c C C C C C C C -a be bebe b i0 be io be be be be be . . . . be be io be be Lo be be to to be io be Ln be ti be f1 .-i be be be be be be be be - . - - .-i .-1 .--1 .-1 .-1 .-V .i .-i .-1 .-i .H .-1 .-1 .-I .-1 .-i ti 4- ON ++ O O 0000000000000000000000000 0 0 0 0 0 0 U o ti ti - ti ti ti ti ti ti ti ti ti - - '1 e1 r1 1-1 ri e-1 i - be '1 .-1 .-1 .-1 .-1 .-1CI OOm mti MmmMMMMMMMMMMMMMMMMMMMMMm MMMMMM ---...\\\---...\\\\\\\\\\\\\\\\\\\---... tiytititiytibemotititimobetiti� tititi.ti 1 . be be .re be be be .i be -t be 44 00 +. a+ ...� 0 c 01\ z > >- > > z z z > > z z z Z z z z > > > > > >" > Z > z z >- > > > > > z z z z z z > > > > > > > > > h O C O Oi . h C C O O v 0 Y N Z > > > 2 Z 2 2 2 Z Z 2 > > 2 2 2 2 2 2 2 2 Z Z 2 2 2 > 2 2 Z Z 2 > 2 2 Z 2 2 2 > > > > > > > > > 3 o O y t G a a . `^ .� s y+ v p yi > > > z z z z z z z z > > z z z z z z z z z z z z z > z z z z z > z z z z z z z z z z 2 z Z z z t. E 3 = i' o N - >v m m 3 L^ QW = Z 2 2 2 2 2 2 2 Z Z Z Z 2 2 2 Z 2 2 2 2 2 2 2 2 2 Z 2 2 Z 2 2 Z 2 2 Z 2 2 2 2 2 2 2 2 2 Z 2 2 2 2 N O1 0 3 O. O Ol C C C C a a a a a a a a a a a a a a a a a a a a a a ¢ a a a a a a ¢ a a a a J J 0000 - - a a a 0 C 0 C7 U' C7 U' l7 C7 (7 (7 C7 0 0 0 C7 0 C7 C7 C7 C7 C 0 (7 0 0 C7 O C7 C7 C7 l'J (7 0 O O O O O O N N N N O O (7 C7 C7 3 aaaa 0 0 0 0 0 0 0 0 0 0 33333333333333333333333333333 0 o 0 on 0 3 3 3 3 LL a 3 3 3 4- 00000000000000000000000000000000000000000000 N 0 0 0 LL LLL LL LL LL LL LL LL LL LL LL LL LL LL ll LL LY LL LL LL LL LL LL LL LL LL LL LL LL LL LL LL LL LL m m m m m m LL LL LL LL l7 W LL LL .11 0) E a 0 N m m > to co t0 > O O O X > r a N 2 O O 000 . 00 O N r W 0 a M OO W on M 00 O O O O N M D L0 0 0 .-i .-1 .-i O .-1 N m O .-1 N M M a a 0 0 0 0 N N O O O O LO N M N M .a-1 N N N N a .a-I M m .ti 0a < 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 pO 0 0 0 0 00 0 0 0 0 0 0 Y Y 0 0 0 0 N N N e O N N ti > > > > > > > > > m m C m m CO m CO CO K 0 OBJ Z LL Li a 2 R d LL 7 O a O O a 7 O a E, 2 O O 2 0 „, . . . „:„ = = = = = = = = = Y Y Y Y Y Y Y Y Y U U U U U U C C U U C C C C C U U U U U U U U U U U U U W W W W W W W W Y Z Z Z Z Z Z Z Z Z Z m a a a a a a a cc m cc m cC a m m m m m 0 0 0 10 0 O o 0 0 0 Y Y Y Y Y Y Y Y ZZ ZZZZZZZZZ N N N N N N N N N N N N N N N 0000000000000000000000000000000000000000000000000 It l0 O N N be M a O LO be a N N co be a N a a N be O1 01 a to N to a be N O N M N be be 01 N LO N co M be N 01 01 O O W Ol tO b M N ti N N m N N M N N l0 'i tO a a N N OO b W 01 N tO N N N M O N M N N CJl a N 00 O LO N m m N O m m Qti O .-1 .7 .-1 In ti .01. be be O ci O b O O O O O ti O O O O O O O .i be O .0. .-I .-1 be 0 0 0 0 0 0 0 r1 0 0 0 0 be '1 O M Cr a a a m a a Cr N N N M N a a a a N N N a a a N t0 m M m a be be be be be be O t0 be be be t0 N N O N N be 4 'i 'i 'i e ri O O O O O .M `1 O O .-1 .-1 .-i e .-1 .-1 be be .-I O O .-1 O .-1 .-1 .-1 a 'i e b N N W l0 N` O1 LO O O O .ti Ol be b O N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N be be of be be be be N N N N be N N N O) 0) N N N O) N v N 01 ECD 03 03 CO CO CO CO CO 03 a a a a a a a a a a a a a a a a a a 10 Si m m m CO m - "O "0 "LL0 'N- 'N- 'LLN ON _ = _ _ _ = vC > O>) N> > N OJ 0) N N N N NOOYNNNO YYY LLNLL LOLLJ CC CC CC CC C> C> CC> C> C> C> C> C> C> C> C> 0) 0) O) 0) O N 0) O) O) N OJ N N N tocoY U U U U >, ` `J a) w w ` v ` L) m m r0 m m m > Y Y Y Y Y Y Y Y Y Y C C C C C C C C C C C C C C C U U U U U U U U U (.7 0 0 0 0 (.7 0 C7 0 L L L r L r L L L L O O O O O O O O O O O O O O O > > > > C 0. 0. saaaaaaaF, 3333F, FEs 50 5 5 '5 0 __ _ _ __ __ _ - - - mc cc cc c c C c c c C C m m m am lC N NJ N NJ NJ N N) NJ a) C w C v C C C C C CC C CCCCCCC m 3 3 3 3 3 m m m m m m m m mm U � � 0 0 0 0 0 0 0 Y Y Y Z Z 2 2 2 2 2 2 Z 2 Z N NNNN N N N N co N N N N N v E E a OJ °�• 4. 0 U 13 .2 o a a cU 0 0 OY > >- >- >- >- >- >- >- >- >- >- >- >- >- >- >- >- >- >- >- >- >- >- > C n o c H c c 0 v a Y H > >- > > > > > > > > > > > > > > > > > > > > > > 0 0 h `. s c o ,a 3 Lv o v� z z z z z z z z z z z z z z z z z z z z z z z z v = o v — v In r`e3 -0 Ct a ° z z z z z z z z z z z z z z z z z z z z z z z z 0 3 a o, J J J . . . . . . . . . J . . . . . J J J J J ...... Q00000000000000000000000 4. 0 E o Y rtl M N V V LO Ol Cr a TrMWMM N N M N VI N V1 N N co N m U NJ a 01 m' Q O' M c' D1 v N N Q' N N N o N V Q CSI v N N NJ N 0 0 0 0 0 0 0 0 0 0 0 to m 0 0 0 0 0 0 0 0 0 0 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 N N tun H VVI N N VVI VVI N tI/I H Vul N In N N N H N N N N N 3 LL LL LL LL LL LL LL LL LL LL LL LL LL LL LL LL LL LL LL LL LL LL U- CC CC CC K CC K K OC In CC CC CC OC CC K Of In In In K CC In K In K VI N VI N VI VI VI VI VI V1 N N in N VI V1 N V1 in V1 in in V1 in 000000000 ° 00000000000000 V1 ID ID N o1 )Oa a N. 174 In N N VI 00 N M Ni O N. O N. e O N O N O O O O N N N N O O O O N O 0 0 0 0 0 0 0 00 M V V V O N a N O N 0 0 CO N N N N N N en fn N Q 00 T-.1 N NN NN IN lN tNO l0 N `,E,' tN N N lND d E 0 Z a 0) 0) 0) 0) 0/ 0) 0) 0) 0) 01 0/ 0) 0) 01 0) 01 0) 0) 0) 01 0) 01 0/ 0) ' ' ' ' ' 'i ac oc z cc s c� cc cc cc cc c� z cc cc z cc z a cc c� z c� cc z cccccccccccccccccccccccc O o O O O O O O O O O O O O O O O O O O O O O O C C C C C C C C C C C C C C C C C C C C C C C C , 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 CO 3 3 3 3 3 CO vt N N VI to V1 V1 V1 N VI VI VI N N VI V) VI VI N N h VI N N OF T • • \ � sA THE STATE Alaska Oil and Gas 1447�, of A S KA Conseavati®n Commission •vf _ t4- = 333 West Seventh Avenue Iv GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 oF` ;affix". Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov November 25, 2015 CERTIFIED MAIL— RETURN RECEIPT REQUESTED 7015 0640 0006 0779 5944 Mr. Chad Helgeson Kenai Operations Manager Hilcorp Alaska, LLC P.O. Box 244027 Anchorage,AK 99524-4027 Re: Docket No. OTH-15-032 Failure to Protect Safety Valve System Beaver Creek 24 (PTD 2141120) Beaver Creek 25 (PTD 2141320) Dear Mr. Helgeson: On November 18, 2015 an Alaska Oil and Gas Conservation Commission (AOGCC) Inspector performed an unannounced inspection of the well safety valve systems at Beaver Creek. A Hilcorp Alaska LLC (Hilcorp) representative was contacted and cooperated fully with the unscheduled inspection. The surface safety systems on Beaver Creek wells 24 and 25 failed function tests because of frozen low pressure sensing lines. A copy of the Inspector's report is attached. The facts reported by the AOGCC Inspector indicate a failure to protect the well safety valve systems to ensure reliable operation under the range of weather conditions expected at the well site. Previous AOGCC Inspections at Beaver Creek production pads identified several wells that.did not have well houses to provide protection from winter temperatures. At the time the AOGCC Inspector arrived at the Beaver Creek field ambient temperatures were -12° F, though they warmed to +4°F by the time the inspections were completed. Wells with the safety valve system protected by well houses, heat-traced sensing line and control panel, insulated blanket covering the transmitter, or a combination of these protections were randomly picked to compare with the wells with an unprotected safety valve system. Inspection revealed that Beaver Creek 24 and 25 had no protection from the subfreezing conditions. Both wells failed their respective low pressure sensor performance tests due to frozen pressure sensing lines, preventing the automatic actuation of the surface safety valve. None of the randomly selected wells that had the safety valve system components protected failed. • • Docket Number OTH-15-032. Notice of Violation—Beaver Creek 24&25 November 25,2015 Page 2 of 2 Hilcorp is reminded that a producing well must be equipped with a functional safety valve system as described in 20 AAC 25.265. Paragraph (c)(7) requires the safety valve system to be maintained in good operating condition at all times and protected to ensure reliable operation under the range of weather conditions expected at the well site. Within 14 days of receipt of this letter, you are requested to provide for AOGCC review and approval a written plan describing what has been or will be done in the future to prevent its recurrence at Hilcorp-operated fields in Alaska. Included in the requested response should be a list of Hilcorp-operated wells that do not have well houses or some other suitable protection of the safety valve system components, a timeline for resolution, and plans for retesting the safety valve systems to demonstrate the reliable operation during cold temperatures. Failure to comply with this request will be an additional violation. The AOGCC reserves the right to pursue additional enforcement action in connection with the failure to adequately protect the safety valve systems on Beaver Creek wells 24 and 25. Questions regarding this letter should be directed to Jim Regg at 907-793-1236. Sincerely, Cathy P. Foerster Chair, Commissioner Attachment cc: P. Brooks AOGCC Inspectors RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or 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 of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration,upon denial,this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction,in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration,this order or decision does not become final. Rather,the order or decision on reconsideration will be the FINAL order or decision of the AOGCC,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision on reconsideration. In computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period;the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p.m.on the next day that does not fall on a weekend or state holiday. • • L y 3 o d 3 0 rA V V o g V),2 d o c E w c E t = 4 > m ,T 0 c e o a=i Q, r o v `r., '3 0 o 0 C U IL ,G V II v a o p d d 0 0 y _ y e , H t0 a cn� 33 e.3 ch o 0.w=U a. 4.c.0. U s� o a a 1 Tj a 0 ,o a o ,u d N Ncp = M asU • V 7 • ;' N U7 N 8 � v ,_:- ,2 owa °oNo °— o Wo cc sP. a r as > 0 „ T v o y L N 3 V ” N o 3 0 0 0 g 8 y o g a " 1ea u z v U o.0 z n,2. z a 2 W.. a o ° L. y L. O Na N N w 4) 8 •° 64 ° w C ,' z N o E--, 4 F — — — — 4..) v a w . G `' a eel Cl) L . ' � It •71- 11.) ^) G H ` a Cn � a CD L (7 U,r q C7 C7 C7 "....4 a � 3a � I.) :o a 5 c7 — — — pA '-> ¢ o Q d u F � — — — �- u al dC. `' — — - F V ON N Y a aF U OA CD Ow A N V/ CA w aF 00 CZ. CV O. C o 0.10 cn N N N cri N W — — — — o C) uo0 0 0 0 a. _ • W Q O 7 7 ird N LL)• Q ....\a. p" z N N N N V C N x C• X) A LL] cio 0 0. 0 '�al Z 3 z - N N C C 74 w 40 v z H U.S. Postal Service'° • CERTIFIED MAIL° RECEIPT Domestic Mail Only 0' For delivery information,visit our website at www.usps.com' Certified Mail Fee r- $ 0 Extra Services&Fees(check box,add fee as appropriate) 0 Return Receipt(hardcopy) $ _a 0 Return Receipt(electronic) $ Postmark 0 ❑Certified Mail Restricted Delivery $ Here 0 ❑Adult Signature Required $ 0 0 Adult Signature Restricted Delivery$ 0 Postage $ �p Total Postage and Fees Mr. Chad Helgeson $ Kenai Operations Manager Ln Sent To Hilcorp Alaska, LLC OStreet andApt No.,or PO box Fl P.O. Box 244027 City,stare,zlP+45 Anchorage,AK 99524-4027 '- PS Form 3800,April 2015 PSN 7530-02-000-9047 See Reverse for Instructions • SENDER: COMPLETE TI-ilS SECTION COMPLETE THIS SECTION ON DELIVERY • Complete items 1,2,and 3. A.-Signatur= / • Print your name and address on the reverseX • =gent so that we can return the card to you. / 0 Addressee • Attach this card to the back of the mailpiece, ed by Pr' e)/ C. Date f D livery or on the front if space permits, , n y /A1125 • �` Is delivery a dress different fro tem 1? 0 Yes Mr. Chad Helgeson If YES,enter delivery address elow: 0 No C,1 Soo*goy Kenai Operations Manager Hilcorp Alaska, LLC t)E C 0 3 2015 P.O. Box 244027 Anchorage,AK 99524-4027 11111111111111111111111 111111 II III I ll I1 I III 3. Service Type O Adult Signature 0 Priority Mail Express® CI Registered 0 Adult Signature Restricted Delivery ❑Registered Mail Restricted B"Certified Mail® Delivery 9590 9403 0910 5223 5232 18 ❑Certified Mail Restricted Delivery VA-Return Receipt for ❑Collect on Delivery Merchandise 2. Article Number(Transfer from service label) 0 Collect on Delivery Restricted Delivery 0 Signature ConfirmationTu ed Mail 0 Signature Confirmation 7015 0640 0006 0779 5944 ed Mail Restricted Delivery Restricted Delivery $500) PS Form 3811,July 2015 PSN 7530-02-000-9053 Domestic Return Receipt • • Regg, James B (DOA) From: Warren Camp <wcamp@hilcorp.com> -Z62 iII2s3/1a Sent: Monday, November 23, 2015 12:02 PM To: Regg,James B (DOA) Subject: Beaver Creek Mr. Regg, On Thursday Nov. 20th, we installed heat trace and temporary insulation on our safety valve systems(pressure transmitters,), on Beaver Creek 24 and 25 wells,which do not have well shelters over them. Permanent insulation blankets have been measured, sized and ordered and will be installed on (insert expected date of install). When the next cold temperature event occurs that is below zero deg, we will function test the SVS again on these wells to ensure that this was an effective fix to ensure 365 days/yrs. functionality. Let us know if you have any questions or need additional information. 1 ECOPY MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: November 19, 2015 P. I. Supervisor FROM: Lou Grimaldi SUBJECT: SVS Cold Weather Function Tests Petroleum Inspector Hilcorp Alaska LLC - Beaver Creek - Wednesday, November 18, 2015: I made an unannounced visit to the Beaver Creek Field operated by Hilcorp Alaska LLC. This was a Commission mandated inspection to - ascertain feasibility of operating wells in the Alaska environment without shelters (well houses). I had not notified the personnel prior to arriving at the lease gate. I called and spoke with Warren Camp and informed him I wanted to make an inspection and was given the OK to enter. It was very cold in the field, approximately -12F while coming in on the - lease road, this was a full 15 degrees colder than Kenai. It should be noted that by the time I finished my inspection the temperature had warmed to +4F at the same point on the road. Beaver Creek traditionally has colder temperatures than the surrounding area, usually 10 degrees colder than the city of Kenai. I explained to Mr. Camp that during my last inspection I had observed there were wells that did not have well houses and in discussions with my supervisor, James Regg, it was decided to come back here when the temperatures got well below freezing. Mr. Camp cooperated fully. Lease operator, Troy Galleguillos, performed the tests today. I tested the wells as follows; the test would be successful if the following were observed: 1. Low Pressure Sensor (LPS). These were tested as we would normally during - routine SVS tests (180 or 90 day). A test manifold with a digital test gage was attached to the LPS test port and opened to the LPS sensing line. Once flowing well pressure was observed the sensing line was blocked in from the flow line and the trapped pressure bled until the LPS tripped. 2. Once test manifold was connected and test port valve opened, flowline pressure would be observed on the test gage. Less than flowline pressure indicates frozen sensing line, fail. 3. If full flow line pressure is observed, bleed slowly and observe for activation of SVS pilot system allowing 3-way block and bleed (palm valve) to fall closed. No movement of palm valve = fail. - 4. Once palm valve operates observe for closure of Surface Safety Valve (SSV). Full closure would be indicated by increase in tubing pressure. No movement or less than full travel = fail. ' 5. Open flow line to test manifold, showing no frozen root valves. Less than full flow line pressure = fail. 2015-1118_SVS_BeaverCk_cold-weather_function_lg.docx Page 1 of 2 . • It should be noted that a "function only"test was performed on the SSV's. This did not test the pressure sealing adequacy of the closure on the SSV, only the ability to close. The first two wells tested were Beaver Creek wells 24 and 25. They lacked well houses as well as any heat tracing or blankets. Both wells failed the LPS test by having frozen low pressure sensing lines. The SSV's were manually palmed and closed properly indicating if the sensor lines were clear most likely the system would have worked. On the same pad there were wells with wellhouses. I randomly picked one with the only criteria that the well be online. Beaver Creek 16RD was chosen and when we walked into the wellhouse it was noticeably warm. The test manifold was hooked up and the SVS system tested with passing results. We moved to a different pad and tested Beaver Creek 07A. This well had freezing problems in the past and was fitted with heat tracing on the sensor lines and an insulated blanket for the SSV. This test at first appeared to fail by a frozen sensing line but we noticed that the transmitter used to sense flowline pressure and trip the LPS was fluctuating mildly. I agreed to test the LPS in a modified manner. Instead of bleeding through the test manifold Troy closed the sensing line and "cracked" a fitting under the transmitter. As the pressure bled of the LPS tripped and triggered the SVS at passing pressure. The SSV went closed and sealed. I feel this system was in good working order with the exception of a frozen test port. Observations: The wells in Beaver Creek produce water along with the gas and oil. Protected by shelters, heat tracing, blankets or a combination of all Beaver Creek wells stand a reasonable chance of having a reliable operating SVS. Unprotected it is a safe bet that these wells' SVS will fail from freezing in the Alaska winter. Attachment: SVS Test Report (AOGCC Inspection # sysLG151119064021) 2015-1 118_SVS_BeaverCk_cold-weather_function_lg.docx Page 2 of 2 i �` • ' • Z E a 3 o 3 0 C 7 g V N yy 0 U 7 a) 7 00 COV) CA c o w c w a0g - oN c 0 z o 0c Ki o II 0 i . s. 0 ? > yE ? � ati y C1) r0 o2 vv) > v ammcG a; U © a, ` a 0111 ;; oa •- a > • . ° h y � o 0 N ' y 0Wy O O O NO 0 .o a (A 6 .o E .o it ^ T. i° o a a> 04 ' a = :: 3 a) y v y "' a. y 3 0 0 3 0 , 0 0 o a o 0 3 0 0 o 0 a) H 0 a 0 y ea as z a 3 U S E.c..) z n «: z a:: f. G4 ,, , .i .L OoN f^ I o r. Wcu tt F. .. o N y d 0 a eq o z C� H _ co U a y v H = y R V1 5 nom. E d • ' Cl..) a a° AO VD a a C/1 cs 4s) L _ G fir . W 'tea .. VI r C7 ,'V•, Q Cd7 9 9 �� d - - v--I - 3 Na o � A _ •i.Ecn * NV (I) 00• 0 rtn rn 47 J rolF0 L V y b -c---- C— w0 in Fa a w C V N N oO a. -I--) ^� a \[,iI .rte E" oo 0 a WIN 0. c ...I a) P, N N N N W __ \ 0 U 0 O O 0 y x = tiJ O E nNN N W E o s ow Q d =1 Z N o N 1-11 N N N 0 CO bn 0 I a N W CQ r1 C y z Z 3 z C N N C p a w C.) z a i • Regg, James B (DOA) From: Grimaldi, Louis R (DOA) Sent: Wednesday, November 18, 2015 1:07 PM To: Warren Camp - Cc: Regg,James B (DOA); DOA AOGCC Prudhoe Bay Subject: Beaver Creek At Beaver Creek. Was -12 now 4 above. BC 24 & 25 failed the function test (both lacking well houses) appearance was frozen sensing points. I have been assured that the sensing lines will be heat traced and blankets obtained for the SVS as I required. Until the winterization is completed you will keep the heaters on these two wells. Please advise Mr. Regg when winterization is completed. Lou Grimaldi Lou Grimaldi(on cell) Petroleum Inspector Alaska Oil and Gas Conservation Commission (907)776-5402(Home) (907)252-3409(Cell) 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Tuesday,June 09,2015 8:35 AM To: 'Donna Ambruz' Cc: Chad Helgeson; Stan Porhola;samantha.carlisle@alaska.gov Subject: RE: Sundry Cancellation - Sundry#315-234 - BCU-24- PTD 214-112 Donna, Sundry 315-234 to install Velocity string in BCU-24 will be withdrawn as requested below. Guy Schwartz Senior Petroleum Engineer AOGCC SCANNED JUN 2 5 2015 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: Donna Ambruz [mailto:dambruz©hilcorp.com] Sent: Tuesday,June 02, 2015 9:56 AM To: Schwartz, Guy L(DOA) Cc: Chad Helgeson; Stan Porhola Subject: Sundry Cancellation - Sundry # 315-234- BCU-24 - PTD 214-112 Guy, Please withdraw the above mentioned sundry(Run Velocity String) . Thank you. Donna amblavz Operations/Regulatory Tech Kenai Asset Team Hilcorp Alaska, LLC 3800 Centerpoint Drive,Suite 1400 Anchorage,AK 99503 907.777.8305-Direct 907.777.8310-Fax dambruz@hilcorp.com 1 RBDMS1A JUN 1 0 2015 , STATE OF ALASKA AL .:A OIL AND GAS CONSERVATION COMh. ,ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Lf Repair Well Lf Plug Perforations Lf Perforate 2 Other Ll Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program 0 Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory ❑ 214-112 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20639-00 7.Property Designation(Lease Number): 8.Well Name and Number: A028083 Beaver Creek(BCU)24 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Beaver Creek/Undef Tyonek Gas Pool 11.Present Well Condition Summary: pC� Total Depth measured 11,300 feet Plugs measured 11,120 fe@t '"�` "T" E!\E D true vertical 10,697 feet Junk measured N/A feet I Li N 0 4 2015 Effective Depth measured 11,225 feet Packer measured N/A feet ��true vertical 10,622 feet true vertical N/A feet Casing Length Size MD ND Burst Collapse Structural Conductor 70' 16" 70' 70' Surface 3,187' 9-5/8" 3,187' 2,933' 5,750 psi 3,090 psi Intermediate Production 11,284' 5-1/2" 11,284' 10,681' 10,640 psi 7,460 psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) N/A N/A N/A N/A Packers and SSSV(type,measured and true vertical depth) Swell Pkr;N/A 2,993'MD 2,762'ND 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: 0 0 0 205 2,724 Subsequent to operation: 0 10,116 0 300 1,492 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development Q Service ❑ Stratigraphic 0 Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas Q WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-245 Contact Stan Porhola Email sporholaAhilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature 41,4____ Phone 907-777-8412 Date (o/02_ti s G /0•r5 RBDMS<))\"4 JUN - b 2015 Form 10-404 Revised 10/2012Submit Original Only . / 'O/ Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date BCU 24 50-133-20639-00 214-112 5/1/15 5/1/15 Daily Operations: 05/01/2015- Friday Held PJSM and obtained permit. MIRU Pollard E-line. Spot equipment, MU 20' x 3-3/8" guns and lubricator stab on well. SITP 2,700 psi. Thaw flowline. Blow down well to 1,850 psi. PT lubricator to 250 psi low/4,000 psi high, good test. RIH w/ 20' x 3-3/8" perf guns and GR/CCL. Log correlation pass from 10,200'-9,700'. Correlate to SLB RST 10-30-14. Send in correlation log for verification, make minor adjustment. Perforate Tyonek T3 sands (10,0131-10,0331 with 3-3/8" HC (3-1/8" Connex charges) 60 deg 6 SPF guns. Little indication of firing, POOH. SITP: 2,110 psi when firing, built gradually to 2,650 psi over 60 min. OOH, all shots fired. LD spent gun and lubricator. RD Pollard. • BCU - 24 ACTUAL Pad 3 1,127 FNL, 1,645'FWL, SCHEMATIC Sec. 34, T7N, R10W, S.M. Hilcorp Alaska,LLC Permit IF 214-112 Conductor API#: 50-133-20639-00 .' 16 Too 6 Bottom Prop.Des: FED A-028083 MD 0' 70' KB elevation: 179.2' (18.6'AGL) TVD 0' 70' Lat: N60° 39' 30.871" Long: W151° 1' 2.842" • Spud:, 9/22/2014 16:00 hrs Surface Casing TD: 10/09/2014 06:00 hrs s-5/s" L-80 40 ppf BTC Riq Released: 10/16/2014 16:00 hrs T0' Bottom MD 0' 3,1187'87' • ND 0' 2,933' __ -- 1 12-114"hole Lead Cmt w/525 sks(230 bbls)of Tree cxn=9-1/2"Otis . 12.0 ppg,Class G, Tail Cmt w/230 sks(50 bbls) 8.0"Seal Diameter of 15.4 ppg,Class G, 180 sks(78 bbls)to surface 5-1/8"Modified ID Bore Production Casing TOC(CBL 10/30/14)-2,584' 5-1/2" P-110 17 ppf CDC Top Bottom RA Mkr Jt 5,799' MD 0' 11,284' TVD 0' 10,681' Capillary Tubing (Removed 2102/15) 8-1/2"hole Cmt w/1,945sks(471 bbls)of 15.3 ppg, 3/8"OD 2205 0.049" '') , Class G cmt w/EASYBLOK Stainless Steel Wall Thicknessill Toe Bottom MD 0' 0' III .i RA MkrJt 7,948' TVD 0' 0' 1 04. Casing/Cementing Detail • - 10.4 ppg Mud gl RA MkrJt 8,172' - 11.5 ppg Mud Push(35 bbl) - 15.3 ppg Cement(471 bbl) - 8.5 ppg 3%KCI(255 bbl) 4 17.4 IRA Mkr Jt 8,624' • IRA Mkr Jt 8,934' Z • k4. • `'i ' • RA MkrJt 9,825' Jewelry Depth • 1.Swell Packer(21'Long) 2,993' • 2.CIBP(Proposed,capped w/40'cement) 11,120' Tyonek T3 3.CIBP(Set 11/18/14;Possibly leaking) 11,130' ' RA MkrJt 10,837' Perforations: Zone MD TVD Size_ SPF Date Status Tyonek T3 10,013'-10,033' 9,410'-9,430' 3-1/8" 6 5/01/15 Open Tyonek T18 10,960'-10,970' 10,357'-10,367 3-1/8" 6 12/09/14 Open S. Tyonek T20 11,170'-11,180'10,567'-10,577' 3-1/8" 6 11/16/14 Iso • Tyonek T18 _ 2 ---_ t . '-,-•, -• MkrJt 11,102' Tag @ 11,046'SLM(4/10/15) •R�;,'' 3 4.60"Blind Box Tyonek T20_ Casing Shoe @ 11,284' Max Dogleg: • 6.59°/100'@ 1,034' TD: PBTD: 11,300'MD 11,225'MD Max Inclination: 10,697'ND 10,622'ND 29.4°@ 2,826' Well Name&Number: Beaver Creek Unit#24 Lease: A-028083 County or Parish: Kenai Peninsula BoroughState/Prov: Alaska Country:IUSA Angle©KOP and Depth: 1.5°@ 500' Angle/Perls:J - N/A - Maximum Deviation. 29.4°@ 2,826' Date Completed: 11/16/2014 Ground Level(above MSL): 160.6' _ RKB(above GL): 18.6' •Revised By: Stan Porhola Downhole Revision Date: 5/1/2015 Schematic Revision Date: 6/1/2015 t EI ED • a STATE OF ALASKA MAY 1 $ 2015 AL A OIL AND GAS CONSERVATION CO. SSION GAS WELL OPEN FLOW POTENTIAL TEST. '•l_ VIA 1a.Test: U Initial U Annual LI Special lb.Type Test: U Stabilized Non Stabilized U Multipoint ❑✓ Constant Time ❑ Isochronal ❑ Other: 2.Operator Name: 5.Date Completed: 11.Permit to Drill Number: Hilcorp Alaska, LLC 11/18/2014 214-112 3.Address: 6.Date TD Reached: 12.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage,AK 99503 10/9/2014 50-133-20639-00 4a.Location of Well(Governmental Section): 7.KB Elevation above MSL(feet): 13.Well Name and Number: Surface: 1127'FNL, 1645'FWL,Sec 34,T7N,R1OW,SM,AK 179.2 Beaver Creek(BCU)24 Top of Productive Horizon: 8.Plug Back Depth(MD+TVD): 14.Field/Pool(s): 2630'FSL,2062'FEL,Sec 34,T7N, R1OW,SM,AK 11,225'MD/10,662'ND Total Depth: 9.Total Depth(MD+TVD): Beaver Creek/Undef Tyonek Gas 2992'FSL,3573'FWL,Sec 34,T7N, R1OW,SM,AK 11,300'MD/10,697'ND 4b. Location of Well(State Base Plane Coordinates NAD 27): 10.Land Use Permit: 15.Property Designation: Surface: x- 317464.36 y-2434055.89 Zone- 4 N/A A028083 TPI: x- 319010.78 y-2432517.26 Zone- 4 16.Type of Completion(Describe): Total Depth: x- 319362.85 y-2432161.52 Zone- 4 5-1/2"Production String,Perforated 17.Casing Size Weight per foot, lb. I.D. in inches Set at ft. 19.Perforations: From To 5-1/2" 17 4.892 11,284 10,013'-10,033' 18.Tubing Size Weight per foot, lb. I.D. in inches Set at ft. 9i960'-10,970' N/ACiMa 11,170'-11,180' 20. Packer set at ft: 21.GOR cf/bbl: 22.API Liquid Hydrocardbons: 23.Specific Gravity Flowing Fluid(G): 24a Producing through: 24b.Reservoir Temp: 24c.Reservoir Pressure: 24d.Barometric Pressure(Pa): ❑Tubing ❑� Casing 151 F° 4,943 psia©Datum 9,233' NDSS psia 25. Length of Flow Channel(L): Vertical Depth(H): Gg: %CO2: %N2: %H2S: Prover: Meter Run: Taps: 26. FLOW DATA TUBING DATA CASING DATA Prover Choke Pressure Diff. Temp. Pressure Temp. Pressure Temp. Duration of Flow No. Line X Orifice psig Hw F° psig F° psig F° Hr. Size(in.) Size(in.) 1. X 2,326 60 2,326 60 1 hr 2. - X 2,246 60 2,246 60 1 hr 3. X 2,150 60 2,150 60 1 hr 4. X 2,016 60 2,016 60 1 hr 5. X Basic Coefficient Flow Temp. Super Comp. Pressure Gravity Factor Rate of Flow No. (24-Hour) hw Pm Factor F Factor Q1 Mcfd Fb or Fp Ft g Fpv 1. 10,226 2. 10,425 3. _ 10,621 4. 10,847 5. r- Temperature for Separator for Flowing No. PrT Tr z Gas Fluid Gg G 1. - 0.57 2.` 0.57 �3. Critical Pressure 0.57 - 4. Critical Temperature 0.57 5. Form 10-421 Rev. 7/2009 0 R I G I+dAf .0N REVEL A G A26 2015 Submit in Duplicate Pc 4,057 pct 16,456,E ?f 4,943 pf2 24,430,283 No. Pt Pte Pc2-Pt2 Pw Pw2 Pc2-Pw2 Ps Pse Pf-PsZ 1. 1,903 2,341 5,478,876 18,951,407 2. 1,838 2,261 5,110,764 19,319,519 3. 1,760 2,165 4,685,926 19,744,357 4. 1,651 2,031 4,123,742 20,306,541 5. 25. AOF (Mcfd) 12,719 n 0.853 Remarks: I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed C� _ Title Reservoir Engineer Date 05/14/15 DEFINITIONS OF SYMBOLS AOF Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia Fb Basic orifice factor Mcfd/ 4,wPm Fp Basic critical flow prover or positive choke factor Mcfd/psia Fg Specific gravity factor, dimensionless Fpv Super compressibility factor= 1 dimensionless Ft Flowing temperature factor, dimensionless G Specific gravity of flowing fluid (air=1.000), dimensionless Gg Specific gravity of separator gas (air=1.00), dimensionless GOR Gas-oil ratio, cu. ft. of gas (14.65 psia and 60 degrees F) per barrel oil (60 degrees F) hw Meter differential pressure, inches of water H Vertical depth corresponding to L, feet(TVD) L Length of flow channel, feet(MD) n Exponent(slope)of back-pressure equation, dimensionless Pa Field barometric pressure, psia Pc Shut-in wellhead pressure, psia Pf Shut-in pressure at vertical depth H, psia Pm Static pressure at point of gas measurement, psia Pr Reduced pressure, dimensionless Ps Flowing pressure at vertical depth H, psia Pt Flowing wellhead pressure, psia Pw Static column wellhead pressure corresponding to Pt, psia Q Rate of flow, Mcfd (14.65 psia and 60 degrees F) Tr Reduced temperature, dimensionless T Absolute temperature, degrees Rankin Z Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the Manual of Back-Pressure Testing of Gas Wells, Interstate Oil Compact Commission, Oklahoma City, Oklahoma. Form 10-421 Revised 7/2009 Side 2 8 0 _ o O -13 aO CO O) h CA 0) COCOCO N N N N N LL 0 Q 1, N LL Q N CO CO CO N p C CO CO CO CO > \.\ it O O O O Q N C v N rt i IZ O II IIO •lt. Lf1 1 m o a e-1 -0 -a LL I a 4-1-- 0 O N Q eu 2 o _ I IA E rn cu N oo �i O -. G 'n ^ O) ^ N ri 4a L N LL O a 6 I- LA I- ,- V (1) (h N CO N O W .oO N • -_. a3 0 ° N M M Ce a cooioi0 v . 3 m N v 0 c7 N;56: ai LL C 0 ++ MI N ~- CC 0 0 0 0 0 0 <O 1 p O (O m N W .Nizr p O N V (D eD a N ++ P.-- (N \IF Np5M 'y if(9n' V G x o,m ,-iLIIa .4. -aaaaa Oa r IO) O) O) O) O) (Y1 ^' = v v v V R D II CO x >' c7) i I I m m \N a N a x O) CO N O § CO V N N N N 0) 8 $ � 0 8( ZvSd - Zv}d) 8 LL o O 8 0 0 N 0-N (� Co O u) O M (O a. 0 Orn CO r<O x vv- 0 r 7 ao _ r) .- o N = II II II m D ts C N n N - r m II — a (D (f) I- O( d 1] <-- C < 0 H Y o N V (NO CO� h O m U. Na) m 0 0 0 0 d I < r.2 e.5 NN 0 LL �N @a N N N N N LL OQ X o. II II D Cp N 3 a 23 E m N N LL U >, ai o - -9. 2 u 0 m r m IL ro LL Ta a hi -6m C 3 N LL M W LL E 0 o 2 4 I (4:ccir w\\AIJ/j,s, THE STATE Alaska Oil and Gas =�� '� of T Conservation Commission :. - At ,ASS itt ;_ _ 333 West Seventh Avenue ' .iia^h,, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main 907.279.1433 OFALASY'' C1 Fax: 907 276.7542 Sat* App �Ui5 www.aogcc.alaska.gov Stan Porhola l Operations Engineer _al Hilcorp Alaska, LLC - 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Beaver Creek Field, Undefined Tyonek Gas Pool, BCU 24 Sundry Number: 315-245 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, f4-f-474-•-- Cathy P Foerster �, Chair DATED this 3 day of April, 2015 Encl. RECEIVEC , APR 2 2 2015 STATE OF ALASKA 093 4 12A/i S ALASKA OIL AND GAS CONSERVATION COMMISSION AOGCC f APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon El Plug for Redril ❑ Perforate New Pod❑ Repair WeII❑ Change Approved Program 0 Suspend❑ Plug Perforations❑ Perforate 2 • Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Wel ❑ Stimulate❑ Alter Casing❑ Other:❑ 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Dril Number Exploratory ❑ Development ❑✓ • 214-112 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6_API Number. Anchorage,Alaska 99503 50-133-20639-00 7.If perforating: 8.Well Name and Number: - What Regulation or Conservation Order governs well spacing in this pool? 20AAC25.0550)14) Beaver Creek(BCU)24 Will planned perforations require a spacing exception? Yes ❑ No ❑ • 9.Property Designation(Lease Number): 10.Field/Pool(s): A028083 • Beaver Creek/Undef Tyonek Gas Pool ' 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): 11,300 ' 10,697 ' 11,225 • 10,622 . 11,120 N/A Casing Length Size MD ND Burst Collapse Structural Conductor 70' 16" 70' 70' Surface 3,187' 9-5/8" 3,187' 2,933' 5,750 psi 3,090 psi Intermediate Production 11,284' 5-1/2" 11,284' 10,681' 10,640 psi 7,460 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(t)and ND(ft): N/A;N/A N/A;N/A 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphicn Development n Service n 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 04/30/15 Oil El Gas El• WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Phone: 907-777-8412 Email sDorhola( hilcorD.corrl Printed Name //JJ Stan�Porhola Title Operations Engineer / Signature .1t7� Phone 907-777-8412 Date Y�ZZ./'C ��TT COMMISSION USE ONLY If/ (11( Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 315 - 24-(6 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No © Subsequent Form Required: / Ly o'-f v,c104✓4- t✓/ 3 i5"--.2 ''i) APPROVED BY Approved by: ! COMMISSIONER THE COMMISSION Date:4 .. 6) as Ii OPftjd&j4I4Ifonths t_sSubmit Form and Form 10-403(R vised /2012) from the date of approvalAttachmeuplicate APR 301015 ,40u4�/j ..,,,,s- ..l' z ; ,/ . Well Prognosis Well: BCU-24 Hileorp Alaska,LI) Date:4/22/2015 Well Name: BCU-24 API Number: 50-133-20639-00 Current Status: Shut-In Gas Well Leg: N/A Estimated Start Date: April 30th, 2015 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-112 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (M) AFE Number: Current Bottom Hole Pressure: —4,784 psi @ 10,527' TVD (Based on BHP Survey on 2/08/15) Maximum Expected BHP: —4,784 psi @ 10,527' ND (Based on BHP Survey on 2/08/15) Max. Allowable Surface Pressure: — 3,731 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft) Brief Well Summary Beaver Creek Unit#24 was drilled as a Grass roots monobore completion in 2014 to target gas sands in the Sterling, Lower Beluga,and Tyonek formations.The initial zone perforated in the Tyonek in mid-November was non-productive.This zone was plugged back and the next Tyonek interval (T-18)was perforated.This zone produced gas before hydrates began to form.The hydrates were treated with a capillary string, but the well eventually loaded up with fluid and has been unable to produce with the fluid level very near to surface. It is suspected that the bridge plug set between the T-20 and T-18 zones was leaking and contributing to the formation water loading up in the well.A bridge plug was set and effectively isolated the water from the T-20. Since water cross-flowed into the T-18,the zone is high pressure and the interval is tight,these factors are contributing to shallow hydrate formation in this well. The purpose of this work/sundry is add perforations in the TyzigkT3 to help the well unload fluid and alleviate hydrate formation, ahead of running the tubing velocity string. Notes Regarding Wellbore Condition • Well is SI, unable to sustain flow without forming hydrates. Current SITP is 2,736 psi. E-line Procedure: 1. MIRU E-line, PT lubricator to 4,000 psi Hi 250 Low. a. Tree connection is 9.5" OTIS. b. SITP will be 2,736 psi (Form gas pressure). 2. RU 3-1/8" 6 spf Connex HC wireline guns. 3. RIH and perforate the following intervals: Zone Sands Top (MD) Btm (MD) FT SPF Tyonek T3 10,013' 10,033' 20' 6 a. Bleed tubing pressure to 2,500 psi before perforating. b. Proposed perfs shown on the proposed schematic in red font. c. Correlate using PNL Log dated 10/30/14(PNL Tie-in log). d. Use Gamma/CCL/to correlate. Utilize Press/Temp tool if available. Well Prognosis Well: BCU-24 Ilileor'a�`"�" LL Date:4/22/2015 e. Record tubing pressures before and after each perforating run. f. Proposed intervals are in the Undef Tyonek Gas Pool. g. Distance to nearest well open in same sands= No wells completed in Tyonek. h. Spacing allowance is based on 20 AAC 25.055(a)(4); no wells within 3,000 ft. 4. RD E-line. 5. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic , . BCU - 24 ACTUAL Pad 3 1,127FNL, 1,645'FWL, SCHEMATIC Sec.34, T7N, R10W, S.M. Iilt•orp Alaska. IAA] Conductor Permit#: 214-112 16" X-56 109 ppf API#: 50-133-20639-00Top Bottom Prop.Des: FED A-028083 i,, ., , ho 0' 70' KB elevation: 179.2' (18.6'AGL) rvD o' 70' Lat: N60° 39' 30.871" •. Long: W151° 1' 2.842" Spud: 9/22/2014 16:00 hrs Surface Casing TD: 10/09/2014 06:00 hrs 9-5/8" L-80 40 ppf BTC Rig Released: 10/16/2014 16:00 hrs TO Bottom ,% MD 0' 3,187' ' ND 0' 2,933' 1 12-114"hole Lead Cmt wl 525 sks(230 bbls)of Tree cxn=9-1/2"Otis t^�'� 12.01 ppg,Class G, Tail Cmt w/230 sks(50 bbls) 8.0"Seal Diameter of 15.4 ppg,Class G, 180 sks(78 bbls)to surface 5-1/8"Modified ID Bore Production Casing TOC(CBL 10/30/14)-2,584' 5-1/2" P-110 17 ppf CDC I Top Bottom �RAMkrJt 5,799' MD 0' 11,284' TVD 0' 10,681' Capillary Tubing (Removed 2/02/15) 8-1/2"hole Cmt w/1,945sks(471 bbls)of 15.3 ppg, 3/8'OD 2205 0.049" Class G cmt w/EASYBLOK Stainless Steel Wall Thickness , 70� Bottom MD 0' 0' ' • RA Mkr Jt 7,948' ND 0' 0' Casino/Cementing Detail ' - 10.4 ppg Mud RA Mkr Jt 8,172' - 11.5 ppg Mud Push(35 bbl) - 15.3 ppg Cement(471 bbl) • - 8.5 ppg 3%KCI(255 bbl) ' . RA Mkr Jt 8,624' I . ,RA Mkr Jt 8,934' ' RA Mkr Jt 9,825' Jewelry Depth • 1.Swell Packer(21'Long) 2,993' 2.CIBP(Proposed,capped w/40'cement) 11,120' • 3.CIBP(Set 11/18/14;Possibly leaking) 11,130' I RA MkrJt 10,837' Perforations: Zone MD TVD Size SPF Date Status • Tyonek T18 10,960'-10,970' 10,357'-10,367 3-1/8" 6 12/09/14 Open Tyonek 720 11,170'-11,180'10,567'-10,577' 3-1/8" 6 11/16/14 Iso Tyonek T18"=-- _ 2 .4' -- MkrJt 11,102' Tag @ 11,046'SLM(4/10/15) t, 3 4.60"Blind Box Tyonek T20 { Casing Shoe @ 11,284' Max Dogleg: -::.!'1 �� 6.59°/100'@ 1,034' TD: PBTD: 11,300'MD 11,225'MD Max Inclination: 10,697'ND 10,622'ND 29.4°@ 2,826' Well Name&Number Beaver Creek Unit#24 Lease: A-028083 County or Parish:- Kenai Peninsula Borough State/Prov: Alaska Country.l USA Angle @KOP and Depth: 1.5°@ 500' Angle/Pegs:I N/A Maximum Deviation: 29.4°@ 2,826' Date Completed: 11/16/2014 Ground Level(above MSL): 160.6' _ RKB(above GL): 18.6' Revised By Stan Porhola Downhole Revision Date: 4/10/2015 Schematic Revision Date: 4/18/2015 BCU — 24 PROPOSED Pad 3 1,127 FNL, 1,645'FWL, SCHEMATIC Sec. 34, T7N, R10W, S.M. I I iL•urp ala.ska. I,I.( Permit#: 214-112 Conductor 16" X-56 109 ppf API#: 50-133-20639-00Top Bottom .. L Prop.Des: FED A-028083 MD 0' 70' KB elevation: 179.2' (18.6'AGL) ND 0' 70' Lat: N60° 39' 30.871" Long: W151° 1' 2.842" Spud: 9/22/2014 16:00 hrs Surface Casing TD: 10/09/2014 06.00 hrs 9-5I8" L-80 40 ppf BTC T0' Bottom Rio Released: 10/16/2014 16:00 hrs MD 0' 3,187' ' ND 0' 2,933' '— 1 12-1/4"hole Lead Cmt w/525 sks(230 bbls)of Tree cxn=9-1/2"Otis I 12.0 ppg,Class G, Tail Cmt w/230 sks(50 bbls) 8.0"Seal Diameter of 15.4 ppg,Class G, 180 sks(78 bbls)to surface 5-1/8"Modified ID Bore TOC(CBL 10/30/14)-2,584' I- Production Casing 5-1/2" P-110 17 ppf CDC ' R• A Mkr Jt 5,799' MD Top 0' Bottom 11,284' ND 0' 10,681' Capillary Tubing (Removed 2/02/15) -. 8-1/2"hole Cmt wl 1,945sks(471 bbls)of 15.3 ppg, 3/8"OD 2205 0.049" . ; Class G cmt w/EASYBLOK Stainless Steel Wall Thickness Igp Bottom • MD 0' 0' RA Mkr Jt 7,948' ND 0' 0' Casina/Cementina Detail - 10.4 ppg Mud RA MkrJt 8,172' - 11.5 ppg Mud Push(35 bbl) - 15.3 ppg Cement(471 bbl) • - 8.5 ppg 3%KCI(255 bbl) I .R• A Mkr Jt 8,624' ' . ' R• A Mkr Jt 8,934' ...i . .. RA MkrJt 9,825' Jewelry Depth 1.Swell Packer(21'Long) 2,993' ' 2.CIBP(Proposed,capped w/40'cement) 11,120' Tyonek T3 3.CIBP(Set 11/18/14;Possibly leaking) 11,130' - RA Mkr Jt 10,837' Perforations: Zone MD ND Size SPF Date Status Tyonek T3 10,013-10,033' 9,410'-9,430' 3-118" 6 Proposed Tyonek T1810,960'-10,970' 10,357'-10,367 3-1/8" 6 12/09/14 Open Tyonek T20 11,170'-11,180'10,567'-10,577' 3-1/8" 6 11/16/14 Iso Tyonek T18— _ 2 t k" Ar '• MkrJt 11,102' Tag @ 11,046'SLM(4/10/15) 4.60"Blind Box "? 3 Tyonek T20 _ _ • Casing Shoe @ 11,284' Max Dogleg: � ..'" 6.59°/100'@1,034' TD: PBTD: Max Inclination: 11,300'MD 11,225'MD 10,697'ND 10,622'ND 29.4°@ 2,826' Well Name 8 Number: Beaver Creek Unit#24 Lease: A-028083 County or Parish. Kenai Peninsula Borough State/Prov. Alaska Country:IUSA Angle @KOP and Depth:- 1.5°@ 500' Angle/Perfs:I N/A - Maximum Deviation: 29.4°@ 2,826' Date Completed._ 11/16/2014 Ground Level(above MSL): 160.6' _ RKB(above GL): 18.6' Revised By. Stan Porhola Downhole Revision Date: Proposed Schematic Revision Date: 4/22/2015 Schwartz, Guy L (DOA) From: Stan Porhola <sporhola@hilcorp.com> Sent: Thursday, April 23, 2015 11:59 AM To: Schwartz,Guy L(DOA) Cc: Davies, Stephen F(DOA) Subject: RE: BCU 24(PTD 214-112) Rig workover Guy, A separate sundry for BCU-24 was submitted to add perfs in the Tyonek T-3,just after I submitted the sundry for the Velocity String. This perf job is planned to go ahead of the planned Velocity String installation sundry and we still plan to execute both jobs. Stan From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Wednesday, April 22, 2015 11:42 AM To: Stan Porhola Cc: Davies, Stephen F(DOA) Subject: RE: BCU 24(PTD 214-112 ) Rig workover Also in step 26 are you using SL to pull the lowest DV and install a OV to circulate out the brine? Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTLALf1YNOTKE: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: Schwartz, Guy L(DOA) Sent: Wednesday, April 22, 2015 11:40 AM To: Stan Porhola Cc: 'Davies, Stephen F(DOA) (steve.davies@alaska.gov)' Subject: BCU 24(PTD 214-112 ) Rig workover Stan, The BHP on BCU 24 indicates the 8.4 ppg lease water will not be heavy enough to use as KWF. You will need to find some higher weight fluid to get above the 8.7 ppg EMW for the formation pressure.( Even with the glass disk in the packer tail ). Guy Schwartz Senior Petroleum Engineer AOGCC 1 9Q7.301-4533 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). 2 (-",of Tye\�\��y,:,& THE STATE Alaska Oil and Gas ��� OLASKA Conservation Commission 'Witt _. = __ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 wa Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Stan Porhola SCOW � APR 2 2015 Operations Engineer Alaska, LLCap-i- - IP- Hilcorp 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Beaver Creek Field, Undefined Tyonek Gas Pool, BCU 24 Sundry Number: 315-234 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, Cathy P Foerster Chair DATED this 2 y day of April, 2015 Encl. RECEIVED STATE OF ALASKA A u R 2 I „ 115 • ALASKA OIL AND GAS CONSERVATION COMMISSION &7-f 4 ?/f- APPLICATION FOR SUNDRY APPROVALS A • �,�-1CC V 20 MC 25.280 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod❑ Repair Weill] Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing Time Extension❑ Operations Shutdowi❑ Re-enter Susp.Wel ❑ Stimulate❑ Alter Casing Other. Run Velocity String❑✓ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. 4 L. s11,-1 Hilcorp Alaska,LLC Exploratory ❑ Development ❑' • 214-112 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. • Anchorage,Alaska 99503 50-133-2C639-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? 20AAC25.055(04) Beaver Creek(BCU)24 • Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): A028083 Beaver Creek/Undef Tyonek Gas Pool - 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): 11,300 • 10,697 • 11,225 • 10,622• 11,120 N/A Casing Length Size MD ND Burst Collapse Structural Conductor 70' 16" 70' 70' Surface 3,187' 9-5/8" 3,187' 2,933' 5,750 psi 3,090 psi Intermediate Production 11,284' 5-1/2" 11,284' 10,681' 10,640 psi 7,460 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(It): See Attached Schematic See Attached Schematic N/A WA WA Packers and SSSV Type. Packers and SSSV MD(t)end ND(ft): N/A;N/A N/A;N/A 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphicn Development n Service n 14.Estimated Date for 15.Well Status after proposed work: 05/05/15 Commencing Operations: Oil ❑ Gas Q . 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 Porhola Phone: 907-777-8412 Email sDorhola( hiIcorD.com Printed Name Stan Porhola Title Operations Engineer Signature , 7 Phone 907-777-8412 Date 4-f" 1-1 s COMMISSION USE ONLY / Conditions of approval: Notify Commission so that a representative may witness Sundry Number: t5 - 23`f Plug Integrity ❑ BOP Test [ Mechanical Integrity Test ❑ Location Clearance ❑ Other: 1660 ,p5 ���r 7 r ( MA S P 3 / 30 p-$- ) Spacing Exception Required? Yes ❑ NoSubsequent Form Required: /O -9 C' by:X / APPROVED BY Approved b 7 / COMMISSIONER THE COMMISSION Date: e./.. Z � y ZZ /S Submit Form and Form 10-403(Revised 10/2012) °Rail Glia IN Adfor 1Z months from the date of approval. Attachments in Duplicate RBDMS JS APR 2 8 20154ir V. 21- it Well Prognosis Well: BCU-24 • Ililcorp Alaska,LLQ Date:4/21/2015 Well Name: BCU-24 API Number: 50-133-20639-00 Current Status: Shut-In Gas Well Leg: N/A Estimated Start Date: May 5th, 2015 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-112 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (M) AFE Number: Current Bottom Hole Pressure: - 4,784 psi @ 10,527' TVD (Based on BHP Survey on 2/08/15) Maximum Expected BHP: -4,784 psi @ 10,527' TVD (Based on BHP Survey on 2/08/15) Max. Allowable Surface Pressure: - 3,731 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft) Brief Well Summary Beaver Creek Unit#24 was drilled as a Grass roots monobore completion in 2014 to target gas sands in the Sterling, Lower Beluga, and Tyonek formations.The initial zone perforated in the Tyonek in mid-November was non-productive.This zone was plugged back and the next Tyonek interval (T-18) was perforated.This zone produced gas before hydrates began to form. The hydrates were treated with a capillary string, but the well eventually loaded up with fluid and has been unable to produce with the fluid level very near to surface. It is suspected that the bridge plug set between the T-20 and T-18 zones was leaking and contributing to the formation water loading up in the well. A bridge plug was set and effectively isolated the water from the T-20. Since water cross-flowed into the T-18,the zone is high pressure and the interval is tight,these factors are contributing to shallow hydrate formation in this well. The purpose of this work/sundry is to run a 2-7/8" tubing velocity string with a packer to help unload the water and manage hydrates. Mandrels will be installed to allow running gaslift valves that would allow gaslift to help unload water in the future.The packer will be set on E-line to minimize chance of putting fluid on zone. Notes Regarding Wellbore Condition • Well is SI, unable to sustain flow without forming hydrates. Current SITP is 2,736 psi. E-line Procedure: 1. MIRU E-line, PT lubricator to 4,000 psi Hi 250 Low. a. Tree connection is 9.5" OTIS. b. SITP will be 2,736 psi (Current SITP). 2. RU 5-1/2" packer and tubing tail assembly and GR/CCL tools. 3. RIH and set packer at+/-9,918' MD, with WLEG set above 9,950'. 4. POOH. LD setting tool. 5. Bleed well down to 1,500 psi to confirm packer set and casing isolated. a. Tubing tail will be isolated with the 10,000 psi rated glass disk. b. If glass disk is compromised, i. MIRU Slickline. ii. RIH and set RHCP plug in X-profile at 9,938' MD to isolate tubing. 6. Test casing to 2,500 psi for 30 min and chart. 7. RD E-line. Well Prognosis Well: BCU-24 IliIcor!):tla.ka,l.L Date:4/21/2015 8. Turn well over to production. GL,r 1 WO Rig Procedure: 9. MIRU Moncla #401 WO Rig. 5. 10. Kill well w/8 ;:ppg lease water(should be isolated with glass disk). 11. Set BPV. ND Tree. 12. NU new tubing head. ► 13. NU 7-1/16" BOPE. Set BPV.Test to 250 psi Low/4,000 psi High, annular to 250 psi Low/2,500 psi High (hold each valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. t�•���- a. Notify AOGCC 24 hrs in advance of BOP test. 14. Bleed apy pressure off tubing. Kill well w/8.4 ppg lease water if needed. 15. Pull Ifpd. RU 2-7/8"tubing handling tools. 16. PU and RIH w/2-7/8" tubing and completion jewelry. 17. RIH and land tubing hanger with tubing tail stung into packer and sealbore at 9,919' MD. b. Leave tubing tail to land seals 1' above bottom of seal bore extension at 9,928' MD. c. Space out Gaslift Mandrels per proposed schematic. d. Run dummy valves in all Gaslift Mandrels. • 18. Test tubing to 3,000 psi for 30 min and chart. 19. Test casing to 2,500 psi for 30 min and chart. 20. Lay down landing joint. Set BPV. ND BOPE. NU tree. Pull BPV. 21. Set TWC.Test hanger to 250/5,000 psi. Test tree to 250/5,000 psi. Pull TWC. 22. RD Moncla #401 WO Rig. 23. Turn well over to production in preparation of moving off the Moncla #401 WO Rig. 24. Replace IA x OA pressure gauge if removed (5-1/2" x 9-5/8"). Slickline Procedure: 25. NU gaslift lines and test to 1,500 psi. �� p4i� lam''17� , s ? 26. Gaslift off fluid (lease water) out of tubing and casing to bottom mandrel (approx. 207 bbl). a. Contingency: May choose to utilize Nitrogen Pump instead of gaslift gas. 27. Leave 1,500 psi on tubing. Bleed casing to 750 psi. 28. MIRU Slickline. PT lubricator to 4,000 psi Hi 250 Low. 29. PU drop bar. Drop bar to break glass disk. a. If RHCP plug set, RIH and pull ball and rod. 30. RIH w/2.25" gauge ring to 11,046' MD (tag fill and confirm glass disk is broken). a. Maximum deviation is 29.4° at 2,826' MD. 31. RD Slickline. Attachments: 1. Actual Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Current Wellhead and Tree 5. Proposed Wellhead and Tree • BCU - 24 ACTUAL Pad 3 1,127 FNL, 1,645'FWL, SCHEMATIC Sec.34, T7N, R10W, S.M. ilt•urp Alaska. 1.1.1: • Permit#: 214-112 I Conductor API#: 50-133-20639-00 - '. 16" X-56 109 ppf Toe Bottom Prop.Des: FED A-028083MD 0' 70' KB elevation: 179.2' (18.6'AGL) • ND 0' 70' Lat: N60° 39' 30.871" Long: W151° 1' 2.842" Spud: 9/22/2014 16:00 hrs Surface Casing TD: 10/09/2014 06:00 hrs 9-5/8" L-80 40 ppf BTC Rig Released: 10/16/2014 16:00 hrs Tom Botom MD 0' 3,187' ND 0' 2,933' 1 12-1/4"hole Lead Cmt w/525 sks(230 bbls)of Tree cxn=9-1/2"Otis 12.0 ppg,Class G, Tail Cmt wl 230 sks(50 bbls) 8.0"Seal Diameter ,;`o. of 15.4 ppg,Class G, 180 sks(78 bbls)to surface 5-1/8"Modified ID Bore TOC(CBL 10/30/14)-2,584' ' Production Casing0 17 ppf CDC RA MkrJt 5,799' MD Top Bottom 0' 11,284' ND 0' 10,681' Capillary Tubing (Removed 2102/15) 8-1/2"hole Cmt w/1,945sks(471 bbls)of 15.3 ppg, 3/8"OD 2205 0.049" Class G cmt w/EASYBLOK Stainless Steel Wall Thickness 4 F T� Bottom ' MD 0' 0' RA Mkr Jt 7,948' TVD 0' 0' Casing/Cementing Detail I ' , - 10.4 ppg Mud R• A MkrJt 8,172' - 11.5 ppg Mud Push(35 bbl) - 15.3 ppg Cement(471 bbl) - 8.5 ppg 3%KCI(255 bbl) ' a 'R• A Mkr Jt 8,624' • ' a RA Mkr Jt 8,934' ' R• A Mkr Jt 9,825' Jewelry Depth 1.Swell Packer(21'Long) 2,993' 2.CIBP(Proposed,capped w/40'cement) 11,120' 3.CIBP(Set 11/18/14;Possibly leaking) 11,130' I a R• A MkrJt 10,837' Perforations: Zone MD ND Size SPF Date Status • Tyonek T18 10,960'-10,970' 10,357-10,367 3-1/8" 6 12/09/14 Open Tyonek T2011,170'-11,180'10,567-10,577' 3-1/8" 6 11/16/14 Iso Tyonek T18= 2 '' ♦».. -. MkrJt 11,102' Tag @ 11,046'SLM(4/10/15) 4.60"Blind Box -� '• 3 Tyonek T20 _ Casing Shoe @ 11,284' Max Dogleg: . . 6.59°/100'@ 1,034' TD: PBTD: Max Inclination: 11,300'MD 11,225'MD 29,4°@ 2,826' 10,697'ND 10,622'ND Well Name&Number: Beaver Creek Unit#24 Lease._ A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country:IUSA Angle @KOP and Depth: 1.5°@ 500' Angle/Perfs:I N/A Maximum Deviation. 29.4°@ 2,826' Date Completed: 11/16/2014 Ground Level(above MSL): 160.6' _ RKB(above GL): 18.6' Revised By: Stan Porhola Downhole Revision Date: 4/10/2015 Schematic Revision Date: 4/18/2015 BCU — 24 PROPOSED Pad 3 1,127 FNL, 1,645'FWL, SCHEMATIC Sec.34, T7N, R10W, S.M. Ilileorp Alaska. IAA: Permit#: 214-112 "-------7, ,,,f...., Conductor 16" X-56 109 ppf API#: 50-133-20639-00 "" Top Bottom Prop.Des: FED A-028083j MD 0' 70' KB elevation: 179.2' (18.6'AGL) TVD o' 70' Lat: N60° 39' 30.871" Long: W151° 1' 2.842" 11: 0 � Spud: 9/22/20141' 16:00 hrs Surface Casing 9-5/8" L-80 40 ppf BTC TD: 10/09/2014 06:00 hrs Top Bottom Rig Released: 10/16/2014 16:00 hrs ill � MD 0' 3,187' r______ TVD 0' 2,933' • 5 12-1/4"hole Lead Cmt w/525 sks(230 bbls)of Tree cxn=9-1/2"Otis 7` 12.0 ppg,Class G, Tail Cmt w/230 sks(50 bbls) 8.0"Seal Diameter of 15.4 ppg,Class G, 180 sks(78 bbls)to surface 5-1/8"Modified ID Bore ng TOC(CBL 10/30/14)-2,584' --- Production5 -110 5-1/2" P-110 17 ppf CDC Top Bottom MD 0' 11,284' IL__B TVD 0' 10,681' RA Mkr Jt 5,799' Capillary Tubing (Removed 902/15) - 8-1/2"hole Cmt w/1,945sks(471 bbls)of 15.3 ppg, 3/8"OD 2205 0.049" - _ --- Class G cmt w/EASYBLOK Stainless Steel Wall Thickness Te Bottom , RA MkrJt 7,948' MD 0' 0' TVD 0' 0' . ' 6 RA MkrJt 8,172' f 0-- — ' 1 Casing/Cementing Detail RA Mkr Jt 8,624' - 10.4 ppg Mud - 11.5 ppg Mud Push(35 bbl) - 15.3 ppg Cement(471 bbl) RA Mkr Jt 8,934' - 8.5 ppg 3%KCI(255 bbl) Jewelry Depth I RA Mkr Jt 9,825' 1.Tubing Hanger 18.6' '- . 2.4.50"Gaslift Mandrel(w/dummy valve) 1,400' 3.Chemical Injection Mandrel(valve set @ 1,000 psi) 1,500' 11 4.4.50"Gaslift Mandrel(w/dummy valve) 2,800' t y 5.Swell Packer(21'Long) 2,993' • I 1 ` 7 6.4.50"Gaslift Mandrel(w/dummy valve) 4,200' 12 7.4.50"Gaslift Mandrel(w/dummy valve) 5,600' v3 8.4.50"Gaslift Mandrel(w/dummy valve) 7,000' l 9.4.50"Gaslift Mandrel(w/dummy valve) 8,400' 13 10.4.50"Gaslift Mandrel(w/dummy valve) 9,875' -= ' 11.3.00"Locator Seal Assembly w/6'of seals 9,918' 12.5-1/2"17#Model D Perm Packer 9,919' . 14 13.3.00"Sealbore Extension 9,921' _ 14,2.875"Pup Joint,10'Long 9,928' I•s' 15 15.X-Profile(2.313"ID) 9,938' r• S) ' 16 16.2.875"Pup Joint,10'Long 9,939' _i 17 17.10K Dual Ceramic Disk 9,949' 18.WLEG 9,950' , 18 19.CIBP(Proposed,capped w/40'cement) 11,120' 20.CIBP(Set 11/18/14;Possibly leaking) 11,130' Perforations: ' Zone MD ND Size SPF Date Status I Tyonek T18 10,960'-10,970' 10,357'-10,367 3-1/8" 6 12/09/14 Open ' RA Mkr Jt 10,837' Tyonek T2011,170'-11,180'10,567'-10,577' 3-1/8" 6 11/16/14 Iso Tyonek T18 _ 19 .S •• MkrJt 11,102' Tag @ 11,046'SLM(4/10/15) •...t -� 20 4.60"Blind Box Tyonek T20 _ • • Casing Shoe @ 11,284' Max Dogleg: 6.59°1100'§1,034' TD: PBTD: 11,300'MD 11,225'MD Max Inclination: 10,697'ND 10,622'ND 29.4°@ 2,826' Well Name&Number:_ Beaver Creek Unit#24 Lease: A-028083 County or Parish. Kenai Peninsula Borough State/Prov: Alaska Country USA Angle @KOP and Depth:- 1.5°@ 500' Angle/Perfs.I N/A Maximum Deviation. 29.4°@ 2,826' - Date Completed. 11/16/2014 Ground Level(above MSL): 160.6' _ RKB(above GL):- 18.6' Revised By. Stan Porhola Downhole Revision Date: Proposed Schematic Revision Date: 4/18/2015 Beaver Creek Field BC #24 Current 4/18/2018 I1ikorp U114,1,1.1.1. Beaver Creek Tubing hanger,SMB-22 BC#24ported,11 X 5%-17# 16 x9 5/8 x 51/2 DWC/C csg btm x5.875-4 stub acme LH box top,5" type H BPV prep, 17-4PH material Tree cap,Otis,5 1/8 10M FE X 9'A Otis Quick Union . 0 un..—unml IG.�1 y4 Valve,Swab,WKM-M, *,j C Cy e asaJ roc S1/8lOMFE,HWO, 44'_(' -F 02' 0'4 DD trim *k. ,e, ys yy, roe ao a \0 O9 07) •<e .-11",,3p\ <• c? 1.1.041 Valve,Upper Master, WKM-M,5 1/8 10M FE, HWO,DDtrim �U L Valve,Master,CIW-FC, 4 1( 5 1/8 lOM FE,HWO, �i Beaver Creek Field BC #24 Proposed 4/18/2015 Itilrorp Uu.ki.1.1.1. Beaver Creek BC#24 16 x95/8 x5'Ax 27/8 Tree cap,Otis,2 9/16 5M FE X 6 Y2 Otis Quick Union Valve,Swab,WKM-M, 2 9/16 5M FE,HWO ' DD trim �� Valve,Wing,WKM-M, ��' 2 1/16 5M FE,HWO, Valve,SSV,Barber,3 1/8 5M FE,w/Barber Hydraulic self Valve,Wing,WKM-M, DD trim Y .;;' ""•' contained operator 2 1/16 5M FE,HWO, p DD trim C—r 1� - \ / _ *41111L Valve,Master,WKM-M, 2 9/16 5M FE,HWO, �� DD trim ••„■ „•, Valve,Master,WKM-M, row, 2 9/16 5M FE,HWO, A c DD trim �.`—A_ 1.114•1411.•1 1 :I.alimp I impose; Tubing head,Seaboard-58, I'- .. _ 1 , all MI IM 115MX71/165M r� • °; Gas Lift tie in w/2-2 1/16 5M 55O, 7”P seal bottom 1 Valve,WKM-M,2 1/16 5M JiiEHWOJr. i 1 14•�.r ►_ _ Casing spool,Seaboard-S8, 21 I i�Q- 163/43MX11SM, I w/2-2 1/16 5M SSO, -L Z. I G� 9 5/8 P seal bottom • ( • 1 .•I•= (,t✓' d ...P. Starting head,Seaboard, _41.... .... .r.= ill ....„ _=1 .._ , ,......., 16%3M X16"SOW BTM, �1 w/2-2 1/16 5M SSO 1gi ! I, ! '_ n 16" 9 5/8” 5 A" 2 7/8" Beaver Creek 2015 Moneta Rig 401 na,•„ri, a„oka,c.I.c: Knight Oil Tools BOP - v iii iil iii iii iii lii iii 11 2.57' / Shaffer 7 1/16 5000 J Ifs (ffl(fel mg 7 it 1%1MT-4J Itti ,r____. \ 2 3/8-31/2 variable V i CAMERON I • H H 3.68 ---fl �i in y 41 Blind H 7 1/16 5000, ,,. * I ____ti \ * In III III !mu1.1.I 2 1/16 10M Kill Valves 2 1/16 10M Choke Valves Manual and HCR Manual and HCR 111 111 111 111 1 I l 1.56' IjI a '7 1/16 5000 0 Ø I11 ItI III III I1I' Schwartz, Guy L (DOA) From: Stan Porhola <sporhola@hilcorp.com> Sent: Wednesday, April 22,2015 12:07 PM To: Schwartz, Guy L(DOA) Cc: Davies, Stephen F(DOA) Subject: RE: BCU 24(PTD 214-112) Rig workover Guy, We will run 8.8 ppg(9% KCI)to fill the well (approx. 230 bbl). Stan From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Wednesday, April 22, 2015 11:40 AM To: Stan Porhola Cc: Davies, Stephen F(DOA) Subject: BCU 24 (PTD 214-112 ) Rig workover Stan, The BHP on BCU 24 indicates the 8.4 ppg lease water will not be heavy enough to use as KWF. You will need to find some higher weight fluid to get above the 8.7 ppg EMW for the formation pressure.( Even with the glass disk in the packer tail ). 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(Guv.schwartz@alaska.gov). 1 STATE OF ALASKA AL A OIL AND GAS CONSERVATION COMM. .AON REPORT OF SUNDRY WELL OPERATIONi�, .- "/".... 1.Operations Abandon L] Repair Well U Plug Perforations [ Perforate _ Other CT/N2 Performed. Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program 0 Operat.Shutdown❑ Stimulate-Other 0 Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development Q Exploratory ❑ 214-112 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20639-00 7.Property Designation(Lease Number): 8.Well Name and Number: A028083 Beaver Creek(BCU)24 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): .10.Field/Pool(s): N/A Beaver Creek/Undef Tyonek Gas Pool 11.Present Well Condition Summary: Total Depth measured 11,300 feet Plugs measured 11,130 feeR E ' I V E D true vertical 10,697 feet Junk measured N/A feet l PR 2 1 2 15 Effective Depth measured 11,225 feet Packer measured N/A feet 4 true vertical 10,622 feet true vertical N/A feet C C Casing Length Size MD TVD Burst Collapse Structural Conductor 70' 16" 70' 70' Surface 3,187' 9-5/8" 3,187' 2,933' 5,750 psi 3,090 psi Intermediate Production 11,284' 5-1/2" 11,284' 10,681' 10,640 psi 7,460 psi Liner Perforation depth Measured depth See Attached Schematic SatillE APP. 2 7 2015 True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) N/A N/A N/A N/A Packers and SSSV(type,measured and true vertical depth) Swell Pkr;N/A 2,993'MD 2,762'TVD 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: 0 0 0 0 163 Subsequent to operation: 0 1030 0 0 467 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development Q Service ❑ Stratigraphic 0 Daily Report of Well Operations X 16.Well Status after work: Oil 0 Gas Q WDSPL 0 GSTOR ❑ WINJ ❑ WAG 0 GINJ 0 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: 315-074 Contact Stan Porhola Email sporhola p.hilcorp.com Printed Name / Stan Porhola Title Operations Engineer // Signature .4;117 ��L� Phone 907-777-8412 Date ��2(/ l f RBDMS4 APR 12 20115 Form 10-404 Revised 10/2012 4 V�ti7/5—--- Submit Original Only STATE OF ALASKA AL A OIL AND GAS CONSERVATION COMM._ BION REPORT OF SUNDRY WELL OPERATION 1.Operations Abandon ❑ Repair Well L Plug Perforations [ Perforate _ Other CT/N2 Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development D Exploratory ❑ 214-112 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20639-00 7.Property Designation(Lease Number): 8.Well Name and Number: A028083 Beaver Creek(BCU)24 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Beaver Creek/Undef Tyonek Gas Pool 11.Present Well Condition Summary: Total Depth measured 11,300 feet Plugs measured 11,130 feeR E 11M' E D true vertical 10,697 feet Junk measured N/A feet APR 2 1 2015 Effective Depth measured 11,225 feet Packer measured N/A feet true vertical 10,622 feet true vertical N/A feet AOG A() C C Casing Length Size MD TVD Burst Collapse Structural Conductor 70' 16" 70' 70' Surface 3,187' 9-5/8" 3,187' 2,933' 5,750 psi 3,090 psi Intermediate Production 11,284' 5-1/2" 11,284' 10,681' 10,640 psi 7,460 psi Liner Perforation depth Measured depth See Attached Schematic SCANNED APR 2 f r� 2015 True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) N/A N/A N/A N/A Packers and SSSV(type,measured and true vertical depth) Swell Pkr;N/A 2,993'MD 2,762'TVD 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: 0 0 0 0 163 Subsequent to operation: 0 1030 0 0 467 14.Attachments: 15 Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development Q Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas 0 WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-074 Contact Stan Porhola Email sgorhola(D_hilcorp.com Printed Name / Stan Porhola Title Operations Engineer // /f Signature4--: L+� Phone 907-777-8412 Date �/ 2(/ / RBDMS APR 212 20151 Form 10-404 Revised 10/2012 4 y1 4( 7c- Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date BCU 24 50-133-20639-00 214-112 2/17/15 2/21/15 Daily Operations: 02/17/2015-Tuesday PTW and JSA. Mobe to location and spot equipment. Rig up lubricator and MU 5-1/2" CIBP. Pressure lubricator up to 3,200 psi and pump-in sub leaked.Took back to shop to fix. Pressure test lubricator 250 psi low and 4,500 psi high. RIH with 5-1/2" CIBP and tie into SLB RST 30 Oct 14. Run correlation log and send to town. Get ok to set plug at 11,122' WLM (11,120' RKB). Spotted plug.at 11,122' WLM (11,120' RKB)and set plug with 260 psi on tubing. Lost 300 lbs tool weight when plug set. POOH. Made three 4" x 20' bailer runs of cement (36 gal) amd dumped on top of plug at 11,122' WLM (11,120' RKB). Cement in place at 2045 hrs. Est TOC is 11,086'. Tools got hung up in hole at 1,893' on POOH on last run. Looks like line is stuck in grease tubes. Pollard has a man staying on location tonight and will address line at daylight. 02/20/2015 - Friday PTW and JSA. Mobe to location, spot equipment and rig up. Pressure test 250 psi low and 4,500 psi high. RIH with 4.63" GR and tag top of cement at 11,080' RKB. POOH. MU swab tool string.Tighten bolts up on wireline drum and work on weight indicator. RIH with 2 swab cups for 5-1/2" tubing to 150'. FL was at 12'. Swab from 12' down to 2,150'. Tank measured 38" but tank is not level so will get a bad reading.Tank measurement is suppose to be 2.13 bbls per inch.The 38" was taken on low end.The high end had frozen ice inside tank. Did not see any gas during swabbing. Started tearing up cups so drop soap stick to slick up wall on tubing. Crew change. Continue swabbing from 2,150'to 2,670'. Last run started getting a small gas blow and also acting like gas pushing up fluid level. Cont swabbing to 2,670' and then starting hitting FL higher all the way up to 1,800' to 2,100'. Got about 150 to 160 bbls fluid out. Last 5 runs would get gas back for 3 to 5 min and then quit. 02/21/2015-Saturday Cont swabbing to 2,600' and got about 100 to 110 bbls fluid out. SI well and built to 500 psi in 2 hrs. Bleed well to system and well started unloading. RD Slickline...-Torn-well over to production. NOTE: Did not run coil or reperforate the Tyonek T-18 as planned under Sundry#315-074. fyi/ BCU - 24 ACTUAL Pad 3 1,127 FNL, 1,645'FWL, SCHEMATIC Sec.34, T7N, R10W, S.M. Ililcorp Alaska, I.I.0 Conductor Permit#: 214-112 API#: 50-133-20639-00 16" X-56 109 ppf Top Bottom Prop.Des: FED A-028083 MD 0' 70' KB elevation: 179.2' (18.6'AGL) ND 0' 70' Lat: N60° 39' 30.871" Long: W151° 1' 2.842" qa' Spud: 9/22/2014 16:00 hrs Surface Casinq 9-518" L-80 40 ppf BTC TD: 10/09/2014 06:00 hrs tt Rio Released: 10/16/2014 16:00 hrs 0' Boom MD 0' 3,1187 —,,„ - , •,,`4 ND 0' 2,933' 1 12-1/4"hole Lead Cmt w/525 sks(230 bbls)of Tree cxn=9-1/2"Otis 12.0 ppg,Class G, Tail Cmt w/230 sks(50 bbls) 8.0"Seal Diameter g, of 15.4 ppg,Class G, 180 sks(78 bbls)to surface 5-1/8"Modified ID Bore .A (CBL 10/30/14)-2,584' Production Ca1inq TOC �' 5-1/2" P-110 17 ppf CDC Top Bottom ' RA MkrJt 5,799' MD 0' 11,284' ND 0' 10,681' Capillary Tubing (Removed 2/02/15) 8-1/2"hole Cmt w/1,945sks(471 bbls)of 15.3 ppg, 318"OD 2205 0.049" . Fluid 00 Level Class G cmt w/EASYBLOK Stainless Steel Wall Thickness . Top Bottom MD 0' 0' - RA Mkr Jt 7,948' TVD 0' 0' Casing/Cementing Detail - 10.4 ppg Mud RA MkrJt 8,172' - 11.5 ppg Mud Push(35 bbl) - 15.3 ppg Cement(471 bbl) • • - 8.5 ppg 3%KCI(255 bbl) 1;,,: S. SP RA Mkr Jt 8,624' :.RA Mkr Jt 8,934' • • .t" . 4. • • ' RA Mkr Jt 9,825' Jewelry Depth , 1.Swell Packer(21'Long) 2,993' • 2.CIBP(Set 11/18/14) 11,130' A RA MkrJt 10,837' Perforations: Zone MD ND Size SPF Date Status •. Tyonek T18 10,960'-10,970' 10,357'-10,367 3-1/8" 6 12/09/14 Open Tyonek T20 11,170'-11,180'10,567'-10,577' 3-1/8" 6 11/16/14 Iso a• Tyonek T18 RA MkrJt 11,102' Tag @ 11,062'SLM(3/16115) 4.70"Gauge Ring '+�ti�S`'` 2 Tyonek T20 — _ _ - Casing Shoe @ 11,284' Max Dogleg: - 6.59°/100'@ 1,034' TD: PBTD: Max Inclination: 11,300'MD 11,225'MD 29.4"@ 2,826' 10,697'ND 10,622'ND Well Name&Number Beaver Creek Unit#24 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country IUSA Angle @KOP and Depth: 1.5°@ 500' Angle/Perfs:I N/A Maximum Deviation 29.4°@ 2,826' Date Completed: 11/16/2014 Ground Level(above MSL)._ 160.6' RKB(above GL). 18.6' Revised By: Stan Porhola Downhole Revision Date. 3/16/2015 Schematic Revision Date: 3/21/2015 STATE OF ALASKA • ALS .X OIL AND GAS CONSERVATION COMM, ON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon LJ Repair Well U Plug Perforations U Perforate U Other U Install Capstring Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other 0 Re-enter Suspended WeII❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 2 Exploratory ❑ 214-112 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20639-00 7.Property Designation(Lease Number): 8.Well Name and Number: A028083 Beaver Creek(BCU)24 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Beavr Creek/Undef Tyonek Gas Pool 11.Present Well Condition Summary: RECEIVED Total Depth measured 11,300 feet Plugs measured 11,130 feet ' "' �E I V E true vertical 10,697 feet Junk measured N/A feet FEB B 0 2 2015 Effective Depth measured 11,225 feet Packer measured N/A feet true vertical 10,622 feet true vertical N/A feet OCC Casing Length Size MD ND Burst Collapse Structural Conductor 70' 16" 70' 70' Surface 3,187' 9-5/8" 3,187' 2,933' 5,750 psi 3,090 psi Intermediate Production 11,284' 5-1/2" 11,284' 10,681' 10,640 psi 7,460 psi Liner Perforation depth Measured depth See Attached Schematic �y 3,O&NNED ( Li' (ti 0 12.101-.) True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) N/A N/A N/A N/A Packers and SSSV(type,measured and true vertical depth) Swell Pkr;N/A 2,993'MD 2,762'ND 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: 0 0 0 0 1923 Subsequent to operation: 0 432 0 0 1040 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory 0 Development Service 0 Stratigraphic 0 Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas ❑✓ WDSPL 0 GSTOR 0 WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-001 Contact Stan Porhola Email sporholaOhilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature ...46L J1 - L.4� Phone 907-777-8412 Date 4 OL /S ��J11 RBDMSFEB - 4 2(15 -S ' Form 10-404 Revised 10/2012 � /� Submit Original Only • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date BCU 24 50-133-20639-00 214-112 1/13/15 1/13/15 Daily Operations: 01/13/2015 -Tuesday Rig Up Cap String Truck. Rig up lubricator and 2-7/8" 8RD adapter to 5-1/2" tree. Test to 3,000 psi -test OK. RIH w/3/8" capillary string. Set capillary string @ 3,000'. String pre-loaded with Methanol. RDMO Cap String Truck. • BCU - 24 ACTUAL Il- Pad 3 1,127 FNL, 1,645'FWL, SCHEMATIC Sec.34, T7N, R10W, S.M. Hileorp Alaska,LLC Permit#: 214-112 Conductor API#: 50-133-20639-00 a 16" 56 109ppf Ni. l� Top Bot tom Prop.Des: FED A-028083 ') 't, MD 0' 70' KB elevation: 179.2' (18.6'AGL) •-0 TVD 0' 70' Lat: N60" 39' 30.871" Long: W151° 1' 2.842" Spud: 9/22/2014 16:00 hrs Surface Casing 0 ppf TD: 10/09/2014 06:00 hrs :,A 9-5 /8" L o0 Bottom BTC Rig Released: 10/16/2014 16:00 hrs :i ti� 7 MD 0' 3,18 ND 0' 2,933' ' :.; 1 12-1/4"hole Lead Cmt w/525 sks(230 bbls)of Tree cxn=9-1/2"Otis 12.0 ppg,Class G, Tail Cmt w/230 sks(50 bbls) 8.0"Seal Diameter s4,• of 15.4 ppg,Class G, 180 sks(78 bbls)to surface 5-1/8"Modified ID Bore ,/r.. Production Casing TOC(CBL 10/30/14)-2,584' 5-1/2" P-110 17 ppf CDC Top Bottom RA MkrJt 5,799' MD 0' 11,284' i ND 0' 10,681' Capillary Tubing (Installed 1113115) 8-1/2"hole Cmt w/1,945sks(471 bbls)of 15.3 ppg, 318"OD 2205 0.049" Class G cmt w/EASYBLOK Stainless Steel Wall Thickness Toe Bottom 111MD 0' 3,000' RA MkrJt 7,948' TVD 0' 2,768' Casing/Cementing Detail x - 10.4 ppg Mud RA Mkr Jt 8,172' - 11.5 ppg Mud Push(35 bbl) - 15.3 ppg Cement(471 bbl) - 8.5 ppg 3%KCI(255 bbl) s' _ 1'' RA Mkr Jt 8,624' IRA Mkr Jt 8,934' i:: RA Mkr Jt 9,825' 5 • • Jewelry Depth 1.Swell Packer(21'Long) 2,993' . 2.CIBP(Set 11/18/14) 11,130' ' Perforations: RA MkrJt 10,837' Zone MD ND Size SPF Date Status Tyonek T18 10,960'-10,970' 10,357'-10,367 3-1/8" 6 12/09/14 Open Tyonek T20 11,170'-11,180'10,567'-10,577' 3-1/8" 6 11/16/14 Iso • Tyonek T18—' ' • 4 RA MkrJt 11,102' 2 Tyonek T20 Casing Shoe @ 11,284' Max Dogleg: • 6"59°/1011'@ 1,034' TD: PBTD: Max Inclination: 11,300'MD 11,225'MD 10,697'ND 10,622'ND 29.4°@ 2,826' Well Name&Number: Beaver Creek Unit#24 Lease: A-028083 • County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country:I USA Angle @KOP and Depth: 1.5°@ 500' _ Angle/Perfs.I N/A Maximum Deviation. 29.4°@ 2,826' Date Completed: 11/16/2014 _ Ground Level(above MSL). 160.6' RKB(above GL). 18.6' Revised By: Stan Porhola Downhole Revision Date. 1/13/2015 Schematic Revision Date: 1/19/2015 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 direct inspection of the file. b . i 4_ - L j_j_ Well History File Identifier Organizing(done) ❑ Two-sided ❑ Rescan Needed RES AN: OVERSIZED: NOTES: ofr Items: ❑ Maps: rayscale Items: ogs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: / BY: 412% Date: • I U /3 /s/ re Project Proofing ASIO BY: Date: 4 ' /8 /c /s/ ii I Scanning Preparation x 30 = .a--)0 + 9' = TOTAL PAGES 7 �/ ' (Count does not include cover r SheEt)ifyi BY: Date: c94 I O /s/ Production Scanning rr�� Stage 1 Page Count from Scanned File: c�g (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Igab Date: c9.4 I //5 /s/ Wi p Stage 1 If NO in stage 1, page(s)discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: NO TOTAL PAGES:S 3 Digital version appended by: Meredith \ Michal ell!. ... Date: all 92g) S /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: 333 Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked 7/8/2014 Well History File Cover Page_20140708.doc c O J O O Q N 9 . . Z O O LL . • • t • CMO N N 00`) N 00`) . 0 0 0 0 0 0 0 m E N Z o 'gyp 1 U U U U U N N N N 2 F- N N E N th U DI > > > > > Z N - - N - N - w tj 0 1 } co N CO CO CO CO 7 .-� _ .- .-. .-� .-. • m in >. 0 m m m m CO W = 0 = 0 0 0 0 6 Z Z 2� E E E E E 0 N N a a) a) a) a) E-- _ = CO CO N COco CO U 0 0 0 0 � 0 0 m .0-. y a) u) N a) a) LL' U U 0 0 0 0 0 To CO 1 co itco it co it it It O > > > > > > > m .0 N O N C N a N y N W w N co co Nco co co Q O N f/) f6 fA.- f/) a) m co co Co m m m m m m m m C 9 �+ to co = f�6 ..+ fro fro co J ° c co E m U co c co 0 m- ai J ai hi ai ai ai ai ai 'E O m 0 2 0 y 0 _, 0 j 0 E lL > LL LL LL LL LL LL LL E °L v v O> O L) ° ° ° v 0 co d E •E U •C J •C J •C •C F *E u •C C• C C• C C'.- C J ° O N O N O N O N O N O 0 O a) O O a) O t) O � O a O a I— 0 (n 1, J U ... U ..• U ..• U ._ U ._ U O 0 J 0 J 0 J 0 J 0 C• 0 J 0 J J 1 1 0'C 0'C 0'C 0'C N C 0 Z D w D w 0 LY 0 W a) O 0 w a)W Ce J EO MD MD MD MD MD Mui MO Mu_ MO Mu_ W J W 0 W LL 0 _ �- f/� U v v v v v v v v v v v v v Cl. y O O O O O O O W c° 0 N N N N N N N N N N N N N f0 V CO CO CO CO f0 CO (O CO CO (O CO --CO CO W 0 C.)) a -- o. xx _ 00 Z00 I� I0. N 0 m O M Cr) N C')) m + ,) t - O coN ;;IL LO C Z C t 0 0 G r O F co N- N N N N U V) C) c) a 1' a) ' al O O E a Q 1 V N U m tY Tro J w rez V 1 Q 1 Q co r' oii cm N 0 J2 W0 CON Ois) co J N Y V CL 4O- w LU 0 Q W D J H 1-6 n I c? Q C ! : ,E 0 N co c0 co co co co co co c0 co co c0 11 0 C E 0 0 0 0 0 0 0 0 0 0 0 0 0 o Z'2 m m as ca m m m m m m m m C 0 1 Z O ` 10 0 0 0 0 0 0 0 0 0 0 0 0 N > 0 J ` ) 0 IIr) u) u') u, 1L) u') � Ln � � L0 u) L F , w 0 -0 Tr a a Tr v a v v v v v v v F a) a E ,o o o o o o o o o o o o o Q Z L C a1 Lo = 'i° u) LO u) Lr) LO Lr) � Lo Ln Ir) � I N 1 1 0 O ° w o Z N N N N N N N N N N N N N Q Q G @ £ to w L.Z ) . LLC o o O v 5 CI) G w _CLI o1 Z 2 U U U U U U U o U o U U �7 E 5 1 re a ") - 0 m 0 a < O m ea 0. 0 a a a a a a a a a a a a a a 0 H -Jo > w w w w 111 w w w w w w w w o ,- ,� w o N p 0 J J J m U 0 00 0 O. W W W O 0 CD 0 O 0 C ai rQi co coi E E R N N In I- N N N In H N i— co C`')co M C 0 C.)• co a) a) N O_ 0. w f_ A co - V V V V V V V V Z V Z Z Z D > .0 'C > D > > G). O N N N N N N N N N N (N N N M H O 0 M I- 2 H 2 H T D D D D D D D n 2 D CY CY CC m 0 0 a) aa)) 0 0 0 0 0 0 CY CC CC IX CL 6 Z a)) a)) a) CD 0 0 0 CD w aY) E Q Q Co Co Q Q Q Q Q + H Z a) 2 Cl) a) `) `) N a) 0 Cl) D D co + + C ,C + + + + + 0 0 ( 0 O O U 0 0 v 0 > >_ > y H H I H H H H H H V v v v v v v v v v m- 1 a) N N y N a) N N N ( R a' Q' iL N N N (1 N N N N N N al as co co co CO 03 CO ozi cn a) a) a) a) a) a) a) a) 0 a) > > > a) . 0 0 0 0 0 0 0 0 0 0 < m m m m m m coa0 m m w o w a m m m m m m m m m m C. ai a• i ai ai ai ai ai ai ai ai a a a co o ai ai ai ai ai ai ai ai ai ai I.L it LL it lL it it it it it 2 D 2 0 X LL IL LL IL IL LL LL LL W LL 0 U 0 0 0 0 0 0 0 0 Y(A (A (n U a) U 0 0 0 0 U 0 0 0 0 co• o a o a o Ev o 0 o Y 0 0 0 0 Wp o o o 2 0 0 0 0 0 0 0 0 0 0 I— (/) U J U J U a U U 0 J U U U U O Q O Q O Q U 0 0 0 0 0 0 0 0 0 0 _ I C� a)a' a)W 0 8 a) a) _a)oc a) _N a) a) W '_W V_1L1 _a),tI a) a) a) a) a) a) a) a) a) a) 1~i J W U' W LL W J CO W W CD W W W W N 2 N 2 N 2 W N W W W LU W LU LU W W W 0 1 O a V C V v v V V V V V V V V v V V V V V R v aCl) U O O O O o O O O O O O O O O O O O O O O O O WN N N N N N NNNN N N NNNNNNNNNN < CO (.0 (D CO CO CO (O CO (O CO (O (O CO CO CO CO CO (O CO (O (O (0 r r r r r ; ; ; r ,- ,- WIll o0 (n O. C O.. V0 _ C7 Z O.+ < 1... 0 O 0 O CO 0 Cl, 7 J 0. a, a o u) C O C r O O N. O in C O y M o E v N 0 N Q aa v o N 5 G VW CONin W Y N GC QLLI CO a) < 0 Z E O N (/) m U E U U co Z U) co co co co co CO CO co CO co m m CO Co m m Co m a3 a3 (0 m m a) N. CO CO CO W 76 CO co Co co a) V V co Co Co CO CO CO Co Co CO CO CO 0) 0 0 0 0 0 0 0 0 0 0 N o co 0 0 0 0 0 0 0 0 0 0 0 o a3 c0 a3 a3 Co Co Co CO Co CO I J I CO CO CO CO a3 a3 a3 a3 CO CO CO 0 D D D D D D O D D D J J 0 0 0 0 0 0 0 0 0 0 0 oN > In in In in In in In In in In In In co CO co co co CO CO CO CO CO (O CO • H V V V V V V V V V V V V V V V V V V V V V V V V r O O O 0 O O O O co O O O O O O O O O O O O O O 0 Ln In In In In In In In In in In In In In in In In I() In (0 (0 In In In N N N N N N N NNNNN N N N NNNNNNNNNCN 1 • O G 0 O O w - 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O Ocm O 0 D D D D D D D D D D d 2 W W W W W W W LU LU W J J J W W W W W W W W LU W W o I • a • O '° ._ G V) - h: • O O • • • • p r N O U • O co u) O 0 00 o '° co N Z m1 N mmi l f0 co to ml no 01 a1 a1 of MI W05, W �', E m U a- a0 Eo EN a J In J 2 m Cl c Z 0 w _ _ 8 C oO UDI o o a ..... J ml 0 W y y W ca O u9 Yu) 2 a = a 2 N I �I 7 I ,> a) I I - ai a ai ai ui�_ WI �j ° c N N O E. O °a Z mo mN m,- m�1 Uc U ° 00 0V1 0 0 OJ o m O Q a)2N, a)0I a_ci�1 N y m lo ml yl mo UI ml N m1 ml Tr v Tr N 4 4 N E2 0 2-2 a m 2- 2. Y N N co 'N m Na Na Nal v m 2d c_°ia �a1 0 n n U U ce < WO_ Wiol Ocl O `a3 2a S@l mc maa)) 2E' 2t w m m w C7 cl m a m m -c° aa) ui cl ui a ai.m ci o aid aid < o o < 0 0 M 0 mm 0 w1 LL LL LL�1 LL—w 1 it �l it.°I m LL LL m I C m 1 El-1 °I- °I- 1 El—I °I- °I- c)—y ° y ° 0 a) w El— coo ' 20 20 20 20 20 20 20 20 OLLI OLL1 N o o N E V y I y I m Iola) Im I N a10 a) y v y y v Ce J NN • _ WW _ W _ N Wo W N'° W N WNNWWN CD 43 A (n 0 0 0 0 0 0 0 0 0 0 0 a m 0 Ci. N N N N N N N N N N O O E N E In W O 0 0 0 0 O O O 0 0 N z' v W0 0 O cn o N J a 1 o > co Z m o Is- v- - ,- v IY ° N- CO 0 0 Q) 3CV N J a 0 co a � 11 0n co 0 0 0 0 O oNN N N aII VO U w N 0 JM Q 1 IQ a i o N N 1 To 2 , CO ii Ce cu t 8 m W m 0 N N co 'a (z)W c Q m g L_ a) Q ° a C) Z d0• 1 c c co 03 CIII Z co w m m m m m m m m m m a) m m a) m N. m m m m m m m m m m -o m m -o 0 0 0 0 0 0 0 0 0 0 0 ai 0 0 ai c co o m m m m m m m m m m I m m I 0 0 0• 0 0 0 0 0 0 0 0 J 0 0 J E N > m a) O) O) W O) 0 O) O) O) C)) Un )n an _ I'� W I- V V •V sr V V R '7 47 N N N C ' W W O 0 0 0 0 0 O O O O O co co co )n LL') )n )n co co )n )n U) co co )n co N N N N N N N N N N N N N N N m m W C. Nc _ E E � z ▪ O m m U 0 Oco Z M Q U •" 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 2 0 0 0 m 0 10 0 0 0 0 0 0 0 0 0 c 0 0 p d Z Q a 2 w w W W W W W W W W J W W J 3 In O 0 o 1 N c zol ° cy r caNr Do 7 C Z z t• o q U d 112 Q m m o 7------,- O 0 m I U U J Q U a a 3 y Z Z ' G1 I- c.) t(n N `J ,,,0 J y p it 1 O 0 m m U -r-:,-.) W 5 b ai CeCL. m w it E la 0 m V) l V J• a 0 51, a 2 0 E •J E co Za) COQ :Si O N N CO a. u) s a • 7 0 "a U U Cl. c C � o G Nn O o E U N U m 1 0 J O } O E a Q o o a 0 mc•I 11,3 c G 0o • @ M v _• o W Yo T E re • 0 CO � m m c '8, N Cn W co .0 > H It z Eo c >. CI E U o 2 o z m c v O N N E. a , N > :': T 1 >0 N a = :? m E O m 1 v o :3 0' Ci M c F as Z c m 0 w u o J a m c Uv _ a z o a n v E a UO E o E o o 2 E m y E I E 4 a 2 0 a 0 1 0 0 ci 0 . (col' �����j:sv THE STATE Alaska Oil and Gas �� °fALASKA Conservation Commission t it# _ = = 333 West Seventh Avenue " 'k GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax. 907 276.7542 www.aogcc.alaska.gov Stan Porhola Operations Engineer Hilcorp Alaska, LLC / 3800 Centerpoint Dr., Ste. 1400 al _ F Anchorage, AK 99503 Re: Beaver Creek Field, Undefined Tyonek Gas Pool, BCU 24 Sundry Number: 315-074 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, Cathy P oerster Chair DATED this/ day of February, 2015 Encl. . - RECEIVED STATE OF ALASKA FEB 11 2015 • ALASKA OIL AND GAS CONSERVATION COMMISSION .z I 13 i t 5 APPLICATION FOR SUNDRY APPROVALS AC GCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod❑ Repair WeM❑ Change Approved Program❑ Suspend❑ Plug Perforations 0 • rc-Perforate❑✓ • Pull Tubing Time Extension❑ Operations Shutdown❑ Re-enter Susp.Wel ❑ Stimulate❑ Alter Casing❑ /(,l'L Other. [I I 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill mber. Exploratory ❑ Development 0 • 214-112' 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,Alaska 99503 50-133-20639-00 7.If perforating: 8.Well Name and Number. c.-- What What Regulation or Conservation Order governs well spacing in this pool? 20AAC25.055 ja)(4) Beaver Creek(BCU)24 • Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): A028083 ' Beaver Creek I Undef Tyonek Gas Pool 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): 11,300 • 10,697 ' 11,225 10,622 11,130 N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 70' 16" 70' 70' Surface 3,187' 9-5/8" 3,187' 2,933' 5,750 psi 3,090 psi Intermediate Production 11,284' 5-1/2" 11,284' 10,681' 10,640 psi 7,460 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(R): See Attached Schematic See Attached Schematic N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(t)and ND(ft): N/A;N/A N/A;N/A 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory IT Stratigraphic❑ Development n Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 1,-- 02/18/15 -02/18/15 Commencing Operations: Oil ❑ Gas 0 • 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 Pothole Phane: 907-777-8412 Email sDorholaDhilcorD.Com Printed Name Stan PorholaR'tL_- Title Operations Engineer Signature -� Phone 907-777-8412 Date 2-/ti//s COMMISSION USE ONLY / Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 315 — 0-71—t Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No LJ Subsequent Form Required: /0-1 a 11 APPROVED BY _ Approved by: 7 COMMISSIONER THE COMMISSION Date: 2 —13 -7 11Dr 1 tlN A f6f Z.--,Z.- /� Form and S ubmit Fonn and Form 10-403(Revised 10/2012) A O e a I al 1 Tithe from the date of approval achments in Duplicate RBDMSJ FEB 1 3 2015 ✓ ` --.< , -A. Well Prognosis Well: BCU-24 tlilcor'Alaska.LL' Date:2/11/2015 Well Name: BCU-24 API Number: 50-133-20639-00 Current Status: Shut-In Gas Well Leg: N/A Estimated Start Date: February 18th, 2015 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-112 First Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228(M) Second Call Engineer: Chad Helgeson (907)777-8405 (0) (907) 229-4824(M) AFE Number: Current Bottom Hole Pressure: -4,784 psi @ 10,527' TVD (Based on BHP Survey on 2/08/15) Maximum Expected BHP: -4,784 psi @ 10,527' TVD (Based on BHP Survey on 2/08/15) Max. Allowable Surface Pressure: - 3,731 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft) Brief Well Summary Beaver Creek Unit#24 was drilled as a Grass roots monobore completion in 2014 to target gas sands in the Sterling, Lower Beluga, and Tyonek formations.The initial zone perforated in the Tyonek in mid-November was non-productive.This zone was plugged back and the next Tyonek interval (T-18)was perforated.This zone produced gas before hydrates began to form.The hydrates were treated with a capillary string, but the well eventually loaded up with fluid and has been unable to produce with the fluid level very near to surface. It is suspected that the bridge plug set between the T-20 and T-18 zones is leaking and contributing to the formation water loading up in the well. ti The purpose of this work/sundry is to set an additional plug capped with cement and re-perforate the Tyonek T-18. — ---- Notes Regarding Wellbore Condition • Well is loaded with fluid to 170' RKB. Current SITP is 205 psi. • Bridge plug at 11,130' possibly leaking. E-line Procedure: 1. MIRU E-line, PT lubricator to 4,500 psi Hi 250 Low. a. Tree connection is 9.5" OTIS. b. SITP will be 205 psi (Current SITP,well loaded with fluid). 2. RU 5-1/2" CIBP and GR/CCL tools. 3. RIH and set CIBP at+/- 11,120' MD in the 5-1/2" 17#casing(set 3-5 ft above a casing collar). 4. POOH. LD setting tool. 5. RU 3.50"x20' bailer. 6. RIH tag plug and dump bail 35'of cement on tubing plug(34 gallons of cement)to achieve a cement top at 11,085'. POOH. 7. WOC 24 hrs. 8. RD E-line. 9. Turn well over to production. ti Well Prognosis . • ' - Well: BCU-24 Ilikm„.11,1,k,,.1.1. Date: 2/11/2015 Coiled Tubing Procedure: 10. MIRU Coiled Tubing, PT BOPE to 4,500 psi Hi 250 Low. 11. RU 1.75" coil. MU 2.0"jet nozzle and BHA. 12. RIH w/ 1.75" coil to 11,085' MD and tag top of cement. 13. Displace well fluids with Nitrogen. a. Estimated volume of displaced formation water is 258 bbl. b. Measure starting and ending fluid volumes of flowback tank. 14. Divert well to production separator. 15. POOH w/coil. 16. RD Coiled Tubing. 17. Turn well over to production. E-line Procedure: 18. MIRU E-line, PT lubricator to 4,500 psi Hi 250 Low. a. Tree connection is 9.5" OTIS. b. SITP will be 3,731 psi (Max SITP if gas gradient to surface). 19. RU 3-3/8" 6 spf PowerJet Nova HC wireline guns. 20. RIH and perforate the following intervals: Zone Sands Top (MD) Btm (MD) FT SPF Tyonek T18 10,960' 10,970' 10' 6 a. Bleed tubing pressure to 3,000 psi before perforating. b. Proposed perfs shown on the proposed schematic in red font. c. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. d. Correlate using Cement Bond Log (SCMT Log Dated 10/30/14). e. Use Gamma/CCL/to correlate. Utilize Press/Temp tool if available. J f. Record tubing pressures before and after each perforating run. g. Proposed interval is in the Undef Tyonek Gas Pool. h. Distance to nearest well open in same sands= No offset wells completed in Tyonek. i. Spacing allowance is based on 20 AAC 25.055(a)(4); no wells within 3,000 ft. 21. RD E-line. 22. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic • • BCU — 24 ACTUAL Pad 3 1,127 FNL, 1,645'FWL, SCHEMATIC Sec.34, T7N, R10W, S.M. Flilt-orp.-Alaska- 1.1.1: Permit#: 214-112 Conductor ' L16" X-56 109 ppf API#: 50-133-20639-00 V Fluid Level Top Bottom Prop.Des: FED A-028083 170 MD 0' 70' KB elevation: 179.2' (18.6'AGL) = ND o' 70' Lat: N60° 39' 30.871" Long: W151° 1' 2.842" - Spud: 9/22/2014 16:00 hrs Surface Casing TD: 10/09/2014 06:00 hrs 9-5/8" L-80 40 ppf BTC Rig Released: 10/16/2014 16:00 hrs TOE Bottom MD 0' 3,187' ND 0' 2,933' 1 12-1/4"hole Lead Cmt w/525 sks(230 bbls)of Tree cxn=9-1/2"Otis -_ l 12.0 ppg,Class G, Tail Cmt w/230 sks(50 bbls) 8.0"Seal Diameter . of 15.4 ppg,Class G, 180 sks(78 bbls)to surface 5-1/8"Modified ID Bore .. •Production Casing TOC(CBL 10/30/14)-2,584' 5-1/2" P-110 17 ppf CDC Top Bottom I RA MkrJt 5,799' MD 0' 11,284' ND 0' 10,681' Capillary Tubing (Removed 2/02/151 t 8-1/2"hole Cmt w/1,945sks(471 bbls)of 15.3 ppg, 3/8"OD 2205 0.049" ''..1 .-, Class G cmt w/EASYBLOK Stainless Steel Wall Thickness Top Bottom ..... MD 0' 0' • RA MkrJt 7,948' TVD 0' 0' Casing/Cementing Detail. - 10.4 ppg Mud RA Mkr Jt 8,172' - 11.5 ppg Mud Push(35 bbl) - 15.3 ppg Cement(471 bbl) - 8.5 ppg 3%KCI(255 bbl) ' 4"RA MkrJt 8,624' ' 'a'RA MkrJt 8,934' ' RA Mkr Jt 9,825' Jewelry ( Depth 1.Swell Packer(21'Long) 2,993' 2.CIBP(Set 11/18/14) 11,130' "!� r=, 21 12, I ea RA MkrJt 10,837' Perforations: Zone MD ND Size SPF Date Status Tyonek T18 10,960.-10,970' 10,357'-10,367 3-1/8" 6 12/09/14 Open Tyonek T20 11,170.-11,180'10,567'-10,577' 3-1/8" 6 11/16/14 Iso Tyonek T18 • A,`RA MkrJt 11,102' Tag @ 11,136'SLM(2/03/15) 4.50"Gauge Ring f'.rivii-r , 2 Tyonek T20_ Casing Shoe @ 11,284' Max Dogleg: „... 6.59°/100'@ 1,034' TD: PBTD: Max Inclination: 11,300'MD 11,225'MD 29.4°@ 2,826' 10,697'TVD 10,622'ND Well Name&Number Beaver Creek Unit#24 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country:IUSA - Angle @KOP and Depth. 1.5°@ 500' Angle/Perfs:I N/A Maximum Deviation 29.4°@ 2,826' • Date Completed: 11/16/2014 Ground Level(above MSL). 160.6' _ RKB(above GL): 18.6' Revised By: Stan Porhola Downhole Revision Date. 2/3/2015 Schematic Revision Date: 2/4/2015 .. . . , , • BCU - 24 PROPOSED IIPad 3 1,127 FNL, 1,645'FWL, SCHEMATIC Sec. 34, T7N, R10W, S.M. Hiltorp Alaska. LLC Permit#: 214-112 Conductor API#: 50-133-20639-00 16 Top Bottom Prop.Des: FED A-028083 MD 0' 70' KB elevation: 179.2' (18.6'AGL) ND 0' 70' Lat: N60° 39' 30.871" Long: W151° 1' 2.842" Spud: 9/22/2014 16:00 hrs Surface Casing TD: 10/09/2014 06:00 hrs 9-5/8" L-80 40 ppf BTC Rio Released: 10/16/2014 16:00 hrs T , MD 0'' Bottom ,187' ND 0' 2,933' 1 12-1/4"hole Lead Cmt w/525 sks(230 bbls)of Tree cxn=9-112"Otis 12.0 ppg,Class G, Tail Cmt w/230 sks(50 bbls) 8.0"Seal Diameter of 15.4 ppg,Class G, 180 sks(78 bbls)to surface 5-1/8"Modified ID Bore , Production Casing TOC(CBL 10/30/14)-2,584' — - 5-1/2" P-110 17 ppf CDC Top Bottom RA MkrJt 5,799' MD 0' 11,284' ND 0' 10,681' i Capillary Tubing (Removed 2102115) 40 $" 8-1/2"hole Cmt w/1,945sks(471 bbls)of 15.3 ppg, 318"OD 2205 0.049" :,, ;,,,i$ Class G cmt w/EASYBLOK Stainless Steel Wall Thickness Top Bottom MD 0' 0' , a RA Mkr Jt 7,948' ND 0' 0' Casing/Cementing Detail a - 10.4 ppg Mud III RA Mkr Jt 8,172' - 11.5 ppg Mud Push(35 bbl) - 15.3 ppg Cement(471 bbl) if • - 8.5 ppg 3%KCI(255 bbl) / ' RA Mkr Jt 8,624' 1 • RA Mkr Jt 8,934' !I 4# i I ':' .•RA Mkr Jt 9,825' Jewelry Depth 1.Swell Packer(21'Long) 2,993' • SBP(Proposed,capped w/35'cement) 11,120' 3.CIBP(Set 11/18/14;Possibly leaking) 11,130' 64, tt ' • RA MkrJt 10,837' Perforations:ne ZoMO ND Size SPF Date Status ;j; Tyonek T18 10,960'-10,970' 10,357'-10,367 3-1/8" 6 12/09/14 Open Re-Perf A Tyonek T2011,170'-11,180'10,567'-10,577' 3-1/8" 6 11/16/14 Iso Tyonek T18 7._� -A MkrJt 11,102' Tag @ 11,136'SLM(2/03/15) 4.50"Gauge Ring `"fFf . - 3 Tyonek T20 _ - Casing Shoe @ 11,284' Max Dogleg: 6.59°/100'@ 1,034' TD: PBTD: 11,300'MD 11,225'MD Max Inclination: 10,697'ND 10,622'ND 29.4°@ 2,826' Well Name 8 Number Beaver Creek Unit#24 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country:IUSA Angle @KOP and Depth: 1.5°@ 500' Angle/Perfs:I N/A Maximum Deviation: 29.4°@ 2,826' • Date Completed:. 11/16/2014 Ground Level(above MSL): 160.6' RKB(above GL): 18.6' Revised By: Stan Porhola Downhole Revision Date: Proposed Schematic Revision Date: 2/11/2015 STATE OF ALASKA AL .A OIL AND GAS CONSERVATION COMA, .ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon LJ Repair Well L Plug Perforations L] Perforate L Other Lf Pull Capstring Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other p Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory 0 214-112 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20639-00 7.Property Designation(Lease Number): 8.Well Name and Number: A028083 Beaver Creek(BCU)24 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Beaver Creek/Undef Tyonek Gas Pool 11.Present Well Condition Summary: .x. Total Depth measured 11,300 feet Plugs measured 11,130 °C , E I true vertical 10,697 feet Junk measured N/A feet FE 0 5 2015 Effective Depth measured 11,225 feet Packer measured N/A feet true vertical 10,622 feet true vertical N/A feet A Of3(;"(.; Casing Length Size MD ND Burst Collapse Structural Conductor 70' 16" 70' 70' Surface 3,187' 9-5/8" 3,187' 2,933' 5,750 psi 3,090 psi Intermediate Production 11,284' 5-1/2" 11,284' 10,681' 10,640 psi 7,460 psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) N/A N/A N/A N/A Packers and SSSV(type,measured and true vertical depth) Swell Pkr;N/A 2,993'MD 2,762'ND 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: 0 432 0 0 1040 Subsequent to operation: 0 0 0 0 163 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory 0 Development E Service 0 Stratigraphic 0 Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas Q WDSPL❑ 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: Contact Stan Porhola Email SporholaahiIcorp.com Printed Name Stan Porhola Title Operations Engineer Signature (,,� Phone 907-777-8412 Date 2 0 5' 1 S '6"��'"'666""" / 71:- 21 _,c_ f fi RBDMS \- FEB - 6 2015 Form 10-404 Revised 10/2012 �j ZS /� Submit Original Only /� mil'1/ vir Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date BCU 24 50-133-20639-00 214-112 2/2/15 2/2/15 Daily Operations: 02/02/2015- Monday Rig Up Cap String Truck. Rig up lubricator and adapter. Test to 3,000 psi. POOH w/3/8" capillary string from 3,000'. RDMO Cap String Truck. Turn well over to production. • BCU - 24 ACTUAL Pad 3 1,127 FNL, 1,645'FWL, SCHEMATIC Sec.34, T7N, R10W, S.M. • Ililrorp Alaska. LIA - -- Conductor Permit#: 214-112 16" X-56 109 ppf API#: 50-133-20639-00 Top Bottom Prop.Des: FED A-028083 MD 0' 70' KB elevation: 179.2' (18.6'AGL) TVD 0' 70' Lat: N60° 39' 30.871" Long: W151° 1' 2.842" Spud: 9/22/2014 16:00 hrs Surface Casing TD: 10/09/2014 06:00 hrs 9-SIS" L-80 40 ppf BTC Rig Released: 10/16/2014 16:00 hrs Tom Bottom MD 0' 3,187' • ND 0' 2,933' ___ I — 1 12-1/4"hole Lead Cmt w/525 sks(230 bbls)of Tree cxn=9-1/2"Otis 12.0 ppg,Class G, Tail Cmt w/230 sks(50 bbls) 8.0"Seal Diameter of 15.4 ppg,Class G, 180 sks(78 bbls)to surface 5-118"Modified ID Bore Ilki Production Casing TOC(CBL 10/30/14)-2,584' 5-1/2" P-110 17 ppf CDC On Top Bottom RA MkrJt 5,799' MD 0' 11,284' ND 0' 10,681' i • 8-1/2"hole Cmt w/1,945sks(471 bbls)of 15.3 ppg, Class G cmt w/EASYBLOK RA Mkr Jt 7,948' ce f W a ' Casing/Cementing Detail - 10.4ppg Mud RA MkrJt 8,172' - 11.5 ppg Mud Push(35 bbl) - 15.3 ppg Cement(471 bbl) - 8.5 ppg 3%KCI(255 bbl) 6 RA Mkr Jt 8,624' RA Mkr Jt 8,934' RA Mkr Jt 9,825' Jewelry Depth • 1.Swell Packer(21'Long) 2,993' 2.CIBP(Set 11/18/14) 11,130' a RA MkrJt 10,837' Perforations: Zone MD , ND Size SPF Date Status • Tyonek T1810,960'-10,970' 10,35T-10,367 3-1/8" 6 12/09/14 Open Tyonek T2011,170'-11,180'10,567'-10,577' 3-1/8" 6 11/16/14 Iso Tyonek 118 6 RA MkrJt 11,102' • 2 Tyonek T20 - - Casing Shoe @ 11,284' Max Dogleg: 6.59°/100'@ 1,034' TD: PBTQ: 11,300'MD 11,225'MD Max Inclination: 10,697'ND 10,622'ND 29.4° 2,826' Well Name 8 Number: Beaver Creek Unit#24 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country.I USA Angle @KOP and Depth: 1.5°@ 500' Angle/Perfs.I N/A Maximum Deviation: 29.4°@ 2,826' Date Completed: 11/16/2014 Ground Level(above MSL): 160.6' RKB(above GL): 18.6' Revised By: Stan Porhola Downhole Revision Date: 21212015 Schematic Revision Date: 2/5/2015 II Seth Nolan Hilcorp Alaska, LLC �ry GeoTech 3800 Centerpoint Drive, Suite 100 cam~ Anchorage, AK 99503 DATA LOGGED Tele: 907 777-8308 / /201 IIah',ir1 ti i..,.I.1.( Fax: 907 777-8510 ..!.K.BENDER E-mail: snolan@hilcorp.com DATE 01/23/14 To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 24 Digital Survey Data CD: D BCU 24- Definitive Survey 124+2014 9:25 AM PDF Document 1,640 KB BCU-24 definitive survey 121412014 9:25 AM Text Document 12 KB Please include current contact information if different from above. Please acknowledge receipt by signing and returnin6g one copy of this transmittal or FAX to 907 777.8337 REL ../.) Received By, yAtia.ouDate: ECEI M `J � JAN 2 6 2015 AOGCC STATE OF ALASKA ;f1 EC E I V E D ALAsr A OIL AND GAS CONSERVATION COMMIS—JN s REPORT OF SUNDRY WELL OPERATIONS ,,AN 14 2015 1.Operations Abandon U Repair Well U Plug Perforations LJ Perforate U Other U Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension Li . Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other p Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development Q Exploratory ❑ 214-112 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20639-00 7.Property Designation(Lease Number): 8.Well Name and Number: A028083 Beaver Creek(BCU)24 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Beavr Creek/Undef Tyonek Gas Pool 11.Present Well Condition Summary: Total Depth measured 11,300 feet Plugs measured 11,130 feet true vertical 10,697 feet Junk measured N/A feet Effective Depth measured 11,225 feet Packer measured N/A feet true vertical 10,622 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 70' 16" 70' 70' Surface 3,187' 9-5/8" 3,187' 2,933' 5,750 psi 3,090 psi Intermediate Production 11,284' 5-1/2" 11,284' 10,681' 10,640 psi 7,460 psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) N/A N/A N/A N/A Packers and SSSV(type,measured and true vertical depth) Swell Pkr;N/A 2,993'MD 2,762'TVD 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: 0 0 0 0 3284 Subsequent to operation: 0 820 0 1218 1400 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development Q Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas Q WDSPL❑ GSTOR Li WINJ ❑ WAG Li GINJ ❑ SUSP❑ SPLUG Li 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: 314-650 Contact Stan Porhola Email sporhola(a�hilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature )&0-11\.._ Phone 907-777-8412 Date VP-fill kBLmms . \ J 5 1015 /-;3 --h Form 10-404 Revised 10/20120,7 / - Submit Original Only II- , : Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date BCU 24 50-133-20639-00 214-112 12/9/14 12/9/14 Daily Operations: 12/09/2014-Tuesday PTW and JSA. Mobe to location and spot equipment. Rig up lubricator and PT to 250 psi low and 4,500 psi high. TP-3,050 psi. RIH with 3-3/813-1/8" charges) x 10' Connex HC, 6 spf, 60 deg phase and tied into SLB RST log dated 30-Oct-14. Sent correlation log to town and got ok. Spotted shot from 10,960'to 10,970'.TP was 3,050 psi. Fired gun and POOH. RIH with GPT tool and found fluid level at 10,410'. POOH. Rig down lubricator and turn well over to field. TP built to 3,296 psi in 6 hrs. BCU - 24 ACTUAL Pad 3 1,127 FNL, 1,645'FWL, SCHEMATIC Sec.34, T7N, R10W, S.M. Ililcnty)Alaska. 1.I.(: Permit#: 214-112 Conductor API#: 50-133-20639-00 16" X-56 lot ppm Top Bottom Prop.Des: FED A-028083 MD 0' 70' KB elevation: 179.2' (18.6'AGL) • ND 0' 70' Lat: N60° 39' 30.871" Long: W151° 1' 2.842" Spud: 9/22/2014 16:00 hrs Surface Casing 10/09/2014 06:00 hrs 9-5/8" L-80 40 ppf BTC Bottom Riq Released: 10/16/2014 16:00 hrs 10' • MD 0' 3,187' ND 0' 2,933' I -7-- 1 12-1/4"hole Lead Cmt w/525 sks(230 bbls)of Tree cxn=9-1/2"Otis 12.0 ppg,Class G, Tail Cmt w/230 sks(50 bbls) 8.0"Seal Diameter of 15.4 ppg,Class G, 180 sks(78 bbls)to surface 5-1/8"Modified ID Bore • TOC(CBL 10/30/14)-2,584' Production Casing 5-112" P-110 17 ppf CDC el Top Bottom RA MkrJt 5,799' MD 0' 11,284' ND 0' 10,681' 8-1/2"hole Cmt w/1,945sks(471 bbls)of 15.3 ppg, Class G cmt w/EASYBLOK • RA Mkr Jt 7,948' • Casing/Cementing Detail - 10.4 ppg Mud • RA Mkr Jt 8,172' - 11.5 ppg Mud Push(35 bbl) - 15.3 ppg Cement(471 bbl) - 8.5 ppg 3%KCI(255 bbl) • RA Mkr Jt 8,624' •RA Mkr Jt 8,934' 6 6 RA Mkr Jt 9,825' Jewelry Depth V Fluid Level 1.Swell Packer(21'Long) 2,993' 10,500' 2.CIBP(Set 11/18/14) 11.130' - - -- - -- ------ • RA MkrJt 10,837' Perforations: Zone MD ND Size SPF Date Status Tyonek T18 10,960'-10,970' 10,357-10,367 3-1/8" 6 12/09/14 Open Tyonek T20 11,170'-11,180'10,567'-10,577' 3-1/8" 6 11/16/14 Iso • Tyonek T18 RA Mkr Jt 11,102' • 2 Tyonek 120 • Casing Shoe @ 11,284' Max Dogleg: _ 6.59"/100'@ 1,034' TD: PBTD: Max Inclination: 11,300'MD 11,225'MD 29.4"@ 2,826' 10,697'ND 10,622'ND Well Name&Number: Beaver Creek Unit#24 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov. Alaska Country-IUSA Angle @KOP and Depth: 1.5°@ 500' Angle/Perls.I N/A Maximum Deviation. 29.4°@ 2,826' Date Completed: 11/16/2014 Ground Level(above MSL): 160.6' RKB(above GL). 18.6' Revised By: Stan Porhola Downhole Revision Date: 12/9/2014 Schematic Revision Date: 12/17/2014 2_\2-k,- N,2 VOF " 49,\ �7. s� THE STATE Alaska Oil and Gas ���`' �'� °fALA Ic;A Conservation Commission ' tort-_ __�^- — 333 West Seventh Avenue '" F GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 0.0, Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Stan Porhola Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Beaver Creek Field, Undefined Tyonek Gas Pool, BCU 24 Sundry Number: 315-001 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, 1 Cathy PP/Foerster Chair DATED this --qday of January, 2015 Encl. RECEIVED STATE OF ALASKA ,IAN ALASKA OIL AND GAS CONSERVATION COMMISSION 2 ? 15 pl%r5 APPLICATION FOR SUNDRY APPROVALS 2 i 6` "S 20 AAC 25.280 X6--h 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations ❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdowt❑ Re-enter Susp.Wel ❑ Stimulate❑ Alter Casing❑ Other. Install Capstring❑, • 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number • Exploratory ❑ Development 0 214-112 . 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,Alaska 99503 50-133-2C639-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? 20AAC25.055(a)4) Beaver Creek(BCU)24 • Will planned perforations require a spacing exception? Yes ❑ No 2 9.Property Designation(Lease Number): 10.Field/Pool(s): A028083 ' Beaver Creek/Undef Tyonek Gas Pool - 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): 11,300 10,697 11,225 10,622 11,130 N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 70' 16" 70' 70' Surface 3,187' 9-5/8" 3,187' 2,933' 5,750 psi 3,090 psi Intermediate Production 11,284' 5-1/2" 11,284' 10,681' 10,640 psi 7,460 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(R): See Attached Schematic See Attached Schematic N/A WA N/A Packers and SSSV Type: Packers and SSSV MD(t)and ND(R): N/A;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 Stratigraphicn Development pi 'Service n 14.Estimated Date for 15.Well Status after proposed work: 01/09/15 Commencing Operations: Oil ❑ Gas ❑✓ d WDSPL ❑ Suspended E 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 Pomola Phone: 907-777-8412 Email sDorhola( hiIcorD.co111 Printed Name Stan Porhola Title Operations Engineer Signature I. L Phone 907-777-8412 Date 1 1- 3 1//s{ COMMISSION USE ONLY / Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 3i 6 -no 1 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No M Subsequent Form Required: /0 --'-f c L( 2/� APPROVED BY Approved by: w /) �� COMMISSIONER THE COMMISSION Date: /— 7 _/S i L f- - r Submrt Form and Form 10-403(Revised 10/205 " Approved applicatio r0i RdicGI,NsAnEe date of approval. ! Attachments in Duplicate FIBCMS JAN La 201 Kffi- C-'/' 111 Well Prognosis Well: BCU-24 Hilcorp Alaska,LLQ Date: 12/31/2014 Well Name: BCU-24 API Number: 50-133-20639-00 Current Status: Producing Gas Well Leg: N/A Estimated Start Date: January 9th, 2015 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-112 First Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907)777-8333 (0) (907)444-2881 (M) AFE Number: Current Bottom Hole Pressure: —4,610 psi @ 10,357' ND (Based on Press Tool post-pert) Maximum Expected BHP: —4,610 psi @ 10,357' ND (Based on Press Tool post-pert) Max. Allowable Surface Pressure: — 3,574 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft) Brief Well Summary Beaver Creek Unit#24 was drilled as a Grass roots monobore completion in 2014 to target gas sands in the Sterling, Lower Beluga,and Tyonek formations.The initial zone perforated in the Tyonek T-20 in mid-November . was non-productive.This zone was plugged back and the Tyonek T-18 was perforated in December 2014.This . was a productive zone and is currently producing. The purpose of this work/sundry is to install a capstring to manage hydrate issues. Notes Regarding Wellbore Condition • Well is currently flowing at reduced rates. • Capstring Procedure: 1. MIRU Cap String Truck, PT lubricator to 4,000 psi Hi 250 Low. 2. Install new threaded connection and wellhead packoff. a. Current tree cap is 9.5" Otis w/5-1/8" 10M flanged connections. 3. PU 3/8" capillary string. RIH and set at+/-3,000'. 4. Set spool of remaining line near well. 5. Rig down Cap String Truck. 6. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic BCU - 24 ACTUAL IIPad 3 1,127 FNL, 1,645'FWL, SCHEMATIC Sec.34, T7N, R10W, S.M. Ililcorp Alaska'. IAA: Permit A; 214-112 Conductor 16" X-56 109 ppf API#: 50-133-20639-00Top Bottom Prop.Des: FED A-028083i:'rl. MD 0' 70' KB elevation: 179.2' (18.6'AGL) TVD 0' 70' Lat: N60° 39' 30.871" Long: W151° 1' 2.842" . Spud: 9/22/2014 16:00 hrs Surface Casing TD: 10/09/2014 06:00 hrs - 9-5/8" L-80 40 ppf BTC Rig Released: 10/16/2014 16:00 hrs -13a Bottom MD 0' 3,187' ' TVD 0' 2,933' 1 12-1/4"hole Lead Cmt w/525 sks(230 bbls)of Tree cxn=9-112"Otis . 12.0 ppg,Class G, Tail Cmt w/230 sks(50 bbls) 8.0"Seal Diameter of 15.4 ppg,Class G, 180 sks(78 bbls)to surface 5-1/8"Modified ID Bore . Production Casing . TOC(CBL 10/30/14)-2,584' - 5-1/2" P-110 17 ppf CDC Top Bottom • a a RA MkrJt 5,799' MD 0' 11,284' TVD 0' 10,681' 8-1/2"hole Cmt w/1,945sks(471 bbls)of 15.3 ppg, • Class G cmt w/EASYBLOK a RA Mkr Jt 7,948' Casing/Cementing Detail - 10.4 ppg Mud RA Mkr Jt 8,172' - 11.5 ppg Mud Push(35 bbl) - 15.3 ppg Cement(471 bbl) • - 8.5 ppg 3%KCI(255 bbl) • RA Mkr Jt 8,624' RA Mkr Jt 8,934' RA MkrJt 9,825' Jewelry Depth V Fluid Level 1 Swell Packer(21'Long) 2,993' - 10,500' _ _ „ 2.CIBP(Set 11/18/14) 11,130' Perforations: • RA MkrJt 10,837' Zone MD TVD Size SPF Date Status • • Tyonek T1810,960'-10,970' 10,357'-10,367 3-1/8" 6 12/09/14 Open Tyonek T2011,170'-11,180'10,567'-10,577' 3-1/8" 6 11/16/14 Iso Tyonek T18 RA MkrJt 11,102' _ 2 Tyonek T20 -._ _ Casing Shoe @ 11,284' Max Dogleg: • 6.59°/100'@ 1,034' TD: PBTD: Max Inclination: 11,300'MD 11,225'MD 29.4°@ 2,826' 10,697'TVD 10,622'TVD Well Name&Number Beaver Creek Unit#24 Lease: A-028083 County or Parish.. Kenai Peninsula Borough State/Prov: Alaska Country:IUSA Angle @KOP and Depth: 1.5°@ 500' Angle/Perfs:1 N/A Maximum Deviation: 29.4°@ 2,826' Date Completed: 11/16/2014 Ground Level(above MSL)._ 160.6' RKB(above GL): 18.6' Revised By: Stan Porhola Downhole Revision Date: 12/9/2014 Schematic Revision Date: 12/17/2014 BCU - 24 PROPOSED Pad 3 1,127 FNL, 1,645'FWL, SCHEMATIC Sec.34, T7N, R10W, S.M. Ililc•orp Alaska.LL(; 1 i Permit#: . 214-112 Con..ductor API#: 50-133-20639-00 16 TXo u6 Bott9 om Prop.Des: FED A-028083 LMD 0' 70' KB elevation: 179.2' (18.6'AGL) TVD 0' 70' Lat: N60° 39' 30.871" Long: W151° 1' 2.842" • Spud: 9/22/2014 16:00 hrs Surface Casing TD: 10/09/2014 06:00 hrs 9-5/8" L-80 40 ppf BTC Rio Released: 10/16/2014 16:00 hrs MD T� Bo0' 3,11tom 87' L { TVD 0' 2,933' 1 12.1/4"hole Lead Cmt w/525 sks(230 bbls)of Tree cxn=9-1/2"Otis 12.0 ppg,Class G, Tail Cmt wl 230 sks(50 bbls) 8.0"Staal_Dlameter_ of 15.4 ppg,Class G, 180 sks(78 bbls)to surface !e. ° /4 , TOC(CBL 10/30/14)-2,584' P5 d2ctionP 110 q 17 ppf CDC Top Bottom RA MkrJt 5,799' MD 0' 11,284' TVD 0' 10,681' Capillary Tubing (Proposed Install) /////‘ 8-1/2"hole Cmt w/1,945sks(471 bbls)of 15.3 ppg, 318"OD 2205 0.049" Class G cmt wl EASYBLOK Stainless Steel Wall Thickness , Top Bottom ' MD 0' 3,000' RA Mkr Jt 7,948' TVD 0' 2,768' • Casing/Cementing Detail • - 10.4 ppg Mud RA MkrJt 8,172' - 11.5 ppg Mud Push(35 bbl) - 15.3 ppg Cement(471 bbl) - 8.5 ppg 3%KCI(255 bbl) ' '. RA Mkr Jt 8,624' ' RA MkrJt 8,934' ' . ' RA Mkr Jt 9,825' Jewelry Depth 1.Swell Packer(21'Long) 2,993' 2.CIBP(Set 11/18/14) 11,130' ' Perforations: RA MkrJt 10,837' Zone MD TVD Size SPF Date Status • Tyonek T18 10,960'-10,970' 10,357'-10,367 3-1/8" 6 12/09/14 Open Tyonek T2011,170'-11,180'10,567'-10,577' 3-1/8" 6 11/16/14 Iso Tyonek T18 'RA Mkr Jt 11,102' • 2 Tyonek T20 _ - ' Casing Shoe @ 11,284' Max Dogleg: _ 6.59°/100'@ 1,034' TD: PBTD: 11,300'MD 11,225'MD Max Inclination: 10,697'TVD 10,622'TVD 29.4°@ 2,826' Well Name 8 Number: Beaver Creek Unit#24 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov. Alaska Country:IUSA Angle @KOP and Depth: 1.5°@ 500' Angle/Perfs:I N/A Maximum Deviation 29.4°@ 2,826' Date Completed. 11/16/2014 Ground Level(above MSL): 160.6' RKB(above GL): 18.6' Revised By. Stan Porhola Downhole Revision Date: Proposed Schematic Revision Date: 12/31/2014 Beaver Creek Field BC #24 Current 12/31/2014 Hiiroirix %Ia4a.I.I I Beaver Creek Tubing hanger,SMB-22 BC#24 ported,ll X 514-17# 16 x 9 5/8 x 51/2 DWC/C csg btm x5.875-4 stub acme LH box top,5" type H BPV prep, 17-4PH material Tree cap,Otis,5 1/8 10M FE X 9'/=Otis Quick Union 0 0 frnEirh-lrin 1 ts` 0 yep Valve,Swab,WKM-M, a o tc� at 5 1/8 10M FE,HWO, (i1::):1' • �, �SQa`<<F,` Oa .TJ e�DD trim Ui. �e` 01 ••• c0 t'oetee lenti� Jai 0 OC �e. O''aC l L1 'S Jai �\ o'` co 1:111 LP:.. I CI N -1.0111111.1 Valve,Upper Master, ♦ �� Cr WKM-M,5 1/8 10M FE, Vit. 1-' (4-•HWO,DD trim o. U L.hil : I lei ei ir. Valve,Master,CIW-FC, 1, 5 1/8 10M FE,HWO, ei� 'i, EE trim L Vsillirgi, Ia.. 1 Adapter,Seaboard-EN, 11 5M stdd x 5 1/8 10M top, w/7"PP bottom ■. r MI.N -.ia lI' 1.1���E.- UM g / ,� I�. FTubin head,Seaboard-S8,16 3 4 3M X 11 5M, : :, w/ 2 1/16 5M SS0, �I� �I114, i !III" 9 5 8 P seal bottom 11 ■ • �: Starting head,Seaboard, 16%3M X 16"SOW BTM, 711 ' ' : l 1 or w/2-2 1/16 5M SSO iii �c Llli,,i,:. r 16" 9 5/8" 5 W' Beaver Creek Field , fili BC #24 Proposed 12/31/2014 IIIl,„r11 \l.,41,.1.1.11. Beaver Creek Tubing hanger,SMB-22 BC#24 ported,ll X 5%-17# 16 x9 5/8 x 5 1/2 DWC/C csg btm x5.875-4 stub acme LH box top,5" type H BPV prep, 17-4PH material 3/8"2205 SS Cap String 2-9/16"Threaded Connection w/Packoff Wrnill Threaded 2-7/8"8RD Connection I. ° ° ' Tree cap,Otis,5 1/8 10M FE X 9'A Otis Quick Union p 1/-.o/ 1\.'1 Cir`k Valve,Swab,WKM-M, C ,� ¢s` a ° os oat` 5 1/810M FE,HWO, ili * 00` 4' <.(4,' ) e Oa zJ e 95a ,z.,-.\ DD trim Q G . 2, y �c ‘5' i'`' a Ja Nr O ,e. Oa a`k• \ q T. I e ; / &� ... ,irici_ :41. II illiNiir.4 ..! 111 Valve,Upper Master, ts.1)�C WKM-M,5 1/8 10M FE, 0. HWO,DD trim i G%� Valve,Master,CIW-FC, 44 1y 5 1/8 10M FE,HWO, ri EE trim U (�, .1 /�• Adapter,Seaboard-EN, L. 11 5M stdd x 5 1/8 10M top, I w/7"PP bottom al, 4 — "lit Ct:li ".–I I. ail 1 Tubing head,Seaboard-S8, I I�J 16 3/4 3M X 11 5M, . Ii w/2-2 1/16 5M SSO, ' �' 9 5/8 P seal bottom '1 �;:, • 1 iiii i_ 1117) ./ u ..• „. Starting head,Seaboard, 163/4 3M X 16"SOW BTM, 'w/2-21/16 SM 55010 _ 141,4111_4 •/ ;_ 11 - 1 16" 9 5/8" 5''A" RECEIVED STATE OF ALASKA OFC 1. 9 2014 ALASF..,OIL AND GAS CONSERVATION COMM-- ION ONnEHCOM❑PLETG❑ON ORe ❑ RECOMPLETION❑ nRE❑PORTcIAN ' la.Well Sta 20AAC 25.105 20AAC 25.110 Development 0 ' Exploratory ❑ GINJ H WINJ ❑ WAG ❑ WDSPL❑ No.of Completions: _0 • Service j Stratigraphic Test ❑ 2. Operator Name: 5. Date ComE.,Susp.,or `12. Permit to Drill Number: Hilcorp Alaska,LLC Aband.: 11/1812014 214-112 - 3.Address: 6. Date Spudded: 13.API Number: 3800 Centerpoint Drive.Suite 1400 Anchorage,AK 99503 9/22/2014 50-133-20639-00-00 - 4a. Location of Well(Governmental Section): 7. Date TD Reached: 14.Well Name and Number Surface: 1127'FNL, 1645'FWL.Sec 34,T7N, R1OW,SM,AK • 10/9/2014 Beaver Creek Unit(BCU)24 - Top of Productive Horizon: 8. KB(ft above MSL): 179.2 15. Field/Pool(s): 2630'FSL,2062'FEL,Sec 34,T7N, R1OW,SM.AK GL(ft above MSL): 160.6 Total Depth: 9. Plug Back Depth(MD+TVD): Beaver Creek/Beluga Gas Pool ' 2992'FSL,3573'FWL.Sec 34.T7N,R1 OW.SM,AK - 11,225'TMD/10.662'TVD- 4b. Location of Well(State Base Plane Coordinates, NAD 27): 10.Total Depth(MD+TVD): 16. Property Designation: Surface: x- 317464.36 y- 2434055.89 - Zone- 4 -11.300'TMD/10.697'TVD. A028083 TPI: x- 319010.78 y- 2432517.26 Zone-4 11. SSSV Depth(MD+TVD): 17. Land Use Permit: Total Depth: x- 319362.85 , y- 2432161.52 • Zone- 4 N/A N/A 18. Directional Survey: Yes ❑✓ 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 MC/TVD: FEL 2in/5in,GRL, DEL.(ROP-DGR-ADR-EWR-ALD-CTN 21N/51N MD&TVD),RST.CEL N/A 23. WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16" 109# X-56 18' 80' 18' 80' Driven N/A 9-5/8" 40# L-80 18' 3187' 18' 2934' 12-1/4" 280bb1(230L&50T), 12&15 ppg 5-1/2" 17# P-110 18' 11284' 18' 10697' 8-1/2" 471 bbl 15.3 ppg Class G 24.Open to production or injection? Yes ❑ No ❑ 25. TUBING RECORD If Yes, list each interval open(MD+TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): N/A N/A N/A NA epaii,iti- ., , 26. ACID, FRACTURE,CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes❑ No E _LLL f(1.- ' DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: N/A Test Period -..* Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. N/A 24-Hour Rate 28. CORE DATA Conventional Core(s)Acquired? Yes❑ No E] Sidewall Cores Acquired? Yes ❑ No❑I 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. i-orm 1U-4U/ Kevised i0izuiz CONTirvutuONRtvERSE 9u iGIit 01igiiral Only "' 2--s,rs �`Z.sR E MS JAN - 9 Sib' ,.1-3z .c-tc G 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑� Yes ❑ No If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form, if Permafrost-Top needed,and submit detailed test information per 20 AAC 25.071. Permafrost-Base BC_B1ST 5375 4875 Tyonek 11,170'-11,180'MD, 10,567-10,577'TVD-Tested unsuccessful. V BC_B3ST 5640 5110 BC B3-LST 5716 5177 • BC_B4ST 5847 5294 BELUGA 6474 5882 UBC3 6723 6126 BC_B16ST 7761 7159 LBGT 7824 7222 BC_B18UST 7887 7285 BC_B2OST 8028 7426 BC_B22ST 8225 7622 BC_B26ST 8450 7847 BC_B28ST 8557 7954 BC_B3OST 8825 8222 TYONEK 9313 8710 SR_D1CT 10409 9805 BC_T10ST 10452 9849 BC_T12ST 10666 10062 BC_T18ST 10849 10245 BC_T2OST 11127 10524 31. List of Attachments: Well Schematic,MW vs Depth,Days vs Depth,Definitive Directional Survey,Drilling Composite Report,Casing and Cmt reports&MIT Report 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Stan Porhola Email: sporholat hilcorp.com Printed Name: Stan Porhola Title: Operations Engineer Signature: ,�� Phone: 907-777-8412 Date: 211 q 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 lb: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 BCU - 24 ACTUAL Pad 3 1,127FNL, 1,645'FWL, SCHEMATIC Sec. 34, T7N, R10W, S.M. Ililcorp Alaska,LLC _ Permit#: 214-112 Conductor API#: 50-133-20639-00 t 16" X-56 109 ppf Top Bottom Prop.Des: FED A-028083 MD 0' 70' KB elevation: 179.2' (18.6'AGL) TVD 0' 70' Lat: N60° 39' 30.871" Long: W151° 1' 2.842" Surface Casing Spud: 9/22/2014 16:00 hrs 9-5/8" L-80 40 ppf BTC TD: 10/09/2014 06:00 hrs T� Bottom Rio Released: 10/16/2014 16:00 hrs MD 0' 3,187' - TVD 0' 2,933' . — 1 12-1/4"hole Lead Cmt w/525 sks(230 bbls)of Tree cxn=9-1/2"Otis ', 12.0 ppg,Class G, Tail Cmt w/230 sks(50 bbls) 8.0"Seal Diameter of 15.4 ppg,Class G, 180 sks(78 bbls)to surface 5.1/8"Modified ID Bore e. 6 TOC(CBL 10/30/14)-2,584' - P5 d2ctionP 110 q 17 ppf CDC Top Bottom RA MkrJt 5,799' MD 0' 11,284' TVD 0' 10,681' 8-1/2"hole Cmt w/1,945sks(471 bbls)of 15.3 ppg, .,. Class G cmt w/EASYBLOK RA Mkr Jt 7,948' rd. ' Casing/Cementing Detail - 10.4 ppg Mud RA Mkr Jt 8,172' - 11.5 ppg Mud Push(35 bbl) '', - 15.3 ppg Cement(471 bbl) t. - 8.5 ppg 3%KCI(255 bbl) RA M kr Jt 8,624' ' RA Mkr Jt 8,934' n r RA Mkr Jt 9,825' Jewelry Depth ' , Fluid Level 1.Swell Packer(21'Long) 2,993' t.' 1-.. 10,500' 2.CIBP(Set 11/18/14) 11,130' . RA MkrJt 10,837' Perforations: i Zone MD TVD Size SPF Date Status Tyonek 11,170'-11,180'10,567'-10,577' 3-1/8" 6 11/16/14 Iso *•RA MkrJt 11,102' , 2 Tyonek r Casing Shoe @ 11,284' Max Dogleg: ,...`�'.�'.._.. 6.59°/100'@ 1,034' TD: PBTD: 11,300'MD 11,225'MD Max Inclination: 10,697'TVD 10,622'TVD 29.4°@ 2,826' Well Name&Number: Beaver Creek Unit#24 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country: USA Angle @KOP and Depth. 1.5°@ 500' Angle/Perfs. N/A Maximum Deviation: 29.4°@ 2,826' Date Completed: 11/16/2014 Ground Level(above MSL): 160.6' RKB(above GL): 18.6' Revised By: Stan Porhola Downhole Revision Date 11/18/2014 Schematic Revision Date 11/25/2014 L Y O — O-O n o �, 0 0 '5 L .- fl- - u) 7 Q N f4 o CO - Cr E :�_ E = o) o 0 7 Q_ p o 7 > 0_ C /a� O ' p ca - •� o a) N (d g C L U (R) CO 0 _ •N co N •L Q.V v`C co - :Q p C 7 't ON E a • _o C0 j) QMM a aCO 2N U — �U Y -0 O 47 > YLp7N 7 (6 n V4o O 'O ' n3 U to N O-o — L 45 -oE o 0CO N � zs o Nd -o LE5 4_ SoCMa) E ° 0a) oa3 — U . V oci coca > -- m o " E W It S . U a a E • � o .`- m � � o oU cn = g ° E �� LU "a) C N .Q .2 O Q o in V ._co O O 0 o f o a) Q a m .0 0 0 C @ o O_ C E (6 4 �' ca co 'C O a) O _ L a) p 7 w 'O O N O OQ • L /� O 0 'O - C VJ • N N '-r_, C 0- U C co N a) O 1 O II a O - a -^+- (9 »-' O C I— a) p > p C) ..- c W O U w 7 _ ` _ L 0 _>_ 6 (0 O Q C ` .L-- OU -p a) N > 0) d O .--, 0 V Y CO It a) a) It -c a) OX E Z It D O -O -O C Y - U C C O oo C C p cn C (6 -p` 7 p (n J -0 = = o (B ca E It U m Y a) as -o = U _ .N a) • a) Y E a) O -Y › O CeC C 0_ E 7 0 9 — I� IL — .n o f ..c O a) C N 7 '6 Q O C O N (a . p C cn 7 — o N a) cn -O C p U p- .E C C c- O (6 L G) 'O .0 N OU O 'p O Q. m L E N O (6 �' O -O 7 co C 3 a) 3 Q 4 ( 7 0 0 'N (o 7 �* Q C (-' E T E Q 0) C U C a0tn aSO a . c �•- -a7 . Nm 0 \ U O — Q oO = u) 0doQ , . 0au) a . = OQ '5. (I) mQ o . . _ @ EL0 a = 00' E oT-o Eon.cO 0 — E E al = L -0 E T .- o U CN � NUL Q n o> N ' o 7m' co L 1:(): O O cNd It: u U > Q) E 7 -2 = Y 7 Y � a) , -O > cn a) E Q U a--- n3 L in L Y (d N co E o)m O 03 a) O „- CI. C •• ,_ a) 0 'E o a) o c C 2 0 v- E V ca-O O o C 0_L (6 L .- — N CI'o co E C Y 7 -o -a � o ao 'iii > -oo a) Q= 0 C - V o Y c cn o o n C° > o �° cn o 7 O U Y O (0 -0 "O — L 0- to }� Y COQ 0) - 0 o a a & � •3 .0 � 0 co .0 v, U N .L C p- 0 'o L -0 a) O N Q)'C .L"— O O E � Q > . �o � . E o p C COm a7 U ao o U) .0 3 0ErpY0 W o - 0 coE o)- E 'o r) - m > V 0pai- ,- rI CO 0 i N - ' N 0) 73 N q .0 CEv • 00 O O _I U a) .> O L (� -O• (6 (0 E (q 2O OW Q E o2S Q v = c 7 U - Q p �- Q 0 C v) C/ a) a) 7 .0 Y 7 H Q Y 7 O Q) a) . o - ' p 41 O O *k L .0 L 7 L V 7 M oi Q N a) p .--. C_ o _Q O Q L 7 r o oo v o -- o w73 ) 3 o = °- R ° co -o aco - Q o [o V N Y — N E 7 O C 7 Y OO C U CC 7 M ca LLo o U ( 7 (n U E > E m (a Q n C o N ca co- CO O L (n .- T O (� ca co cin a) J (N O7� "-- c CO 0 op c 3 E o L c o Q Q a aC) a_o ,_ •�-_ N cv o O = O o-._ _ a) p Q _ fl-O L v U ci) co CO 0 o C Y 0 = E E - co Y `o O N 0_ M A o N- r 0) (6 O N — Q. U O O = (n CO O O M N N CN -o .0 U N o 'C 'a U Q U O N LL N C M r N N O N n5 O) _ (Oq U O -o E O > a O -p L 7 = U a) a) V co O N V ca V a) 0) o) O C6 E a) — OCD - C O 0 — (6 co m Y N (n rn U) 1Y C 3 .o O a) -o S a O .2 U) Ii ca 3 .� 0 Z a.) 7.3 ai *k ai ai `o #k 4 O 0 E a) C7 m ita E t w w a Nr v v v Z Y - u- U) Q Q' Q z @ Q Q O N O N O a) C Q ) O co - O N 7 U N N N o a > �' a 0) 0) 0) 0) 0) LL in co o '_ o m O as o Er) ra C3 _ o 3 EO c (U6 > > C w a p)_0 c a) - d N O 0 CO C a OLS ,C 'O a_ E) cn a) CL U ,- U To C p_ CO -00 0 ,- 0) n 0 3 0 o o n Z = m co O to E E 3 c I-0 a)0 y E o � Y U orO ._, 0 > 0a. O 0_ N ` in 4) •c a0 N a p •C ] U a-p �O O O O -O co ,a 0 a) Y " E 0 0) c0j 0 co O tT - > N O :6 C a oIs= rn D o v) 0 0 E f° 0 ,C 0 a 3 > Q 0- ccp @ O > a N Y Cl) C 0 a • a CI) a L a) U) o U 0 = 0 r) co E -c -t 0 0 E ' 3 co 0)" = 'tn p_ N cn Y c SCI)) O 0 > m 5 o) - Q- c to Li a c co U a- L 3 0 ca vC L cu _ O YL - ` I _ Qc mO Oaf O .OL E - ?� .1,1 =„ lon •9-(On LO •E _CO U 0 CO p 0 o a0 s~ N "UO 0 0 N w �p •�O N ••� 0. C O O C O O n c 0 .0 0 �O L N a) I c• a O '0 a (oO_ W. p _a •O a) = U O to '?� N ... ISL � MN N 00 a) Nt a >, II 0 N c .o D) 3 :[ -O a _ � e ` Q' •- I- o = a rn= c c 0 c c > > o a 0 + a - _ a ra o m 0 • _ o c 0• a 0 0 _ CD Ea N 00 Op a N C `� c N 0.Y 0 > CI) 0 - 4- 0 . 0_ ._ vi 0 C U 0 -0 'E 0 *k a) _C LOH O = 0 E •o c O) a 0 caj .. E O •- 0 a' O c a ` 2 E O C ao 3 C O 0) N N w L 0 > ,- .` !L (n O 0 .0 O 0) =L C 0 0= to 0 -o c c 0- E > a m to 0 a� 0 LO �0 o T 0)_ N '3 m . Ne Q a 0 co 0 .- •� 0 N v (o 4= E c 2 L a, U = C Oi OC Y a - 3 C O m O a j J a0 rn .0 c a cn O N Y 0 Y E cn a L c L a E O U O a 0 E O a) - a y = U - p co Q N O O 6 N N (o o �o Cl) U m E ` '� c c0 O N a@ U a Y 4- N O O 0 Y 0- L _ L .a. N (o j 0) a) a 0 .L co CO •QM - ` OM 0 •- C)00'� N C) N N c 0 E .a .c C -p 0 U ,=_r a `n c- Lo ° c 'c� o '0 °r° o (n o = min 3 to -c m me a 3 _ v o 3 O 00 ao @ - o U o o o m o D - ate) 0) @ Q rn O L co o _o a a-= ao a) •aa a 0) a c ,- a� ,..• c C U o U 0 0 E � 0 O 0 a 0o O , 0 a .. co C a -0co M • 3 `� 3 CL 3m cco TO oZ) a3 E mZ in �? a < m _ O- op EoY U) O yw C �O a � �- n C •- 0w . c to acm cil c co co _a (.0 �r � o NN as YO "6L � 'j co co a) > 0 N O • O co E � a-•> N E � N a) � _ � c � a) n- � U � f6 > a co @ M c a Lo O. a o rnH o_ o _0 0 N •- E c > •��-° m o 00 Q > -o e �` O L L •- 0 -p L.L. a 0 E a C (6 rn 0 Q 0 •` (o 'd VMO a 1- 0 a O) c O O 0. U a E -0 > C -O co tan C F- a 0 U U d-Np a co L o E N L o_ tapY .c .0 0 - 0 O -- 0 Q4) 0 N _a 0) a c O (Co N a b C o_ LL Cs_ U ` V 0) - 0 -- c r 7 E 0 a E -' C O) rn o (n a E rn a 'sT di»-- 0 a3 c ate.• o N Ii �0- 0 ca Ct'9 3 o c L a)is = -o 0- E c_ O c a) C c 0 co_ .0 Y Q O U - O o = to LL c▪ o40 O � O tcaoa��iao CO� t .EaE � 0 U to NIX 0)0 .0 C C7 o � � `O a E Co Y '�m Q ` ca) ca) ..- 0 - 0 - N °o ca) u E N rI •g o m a c E rn@ u) a ,_ a a) a) up) -o 77 C (n m to co 0 0 12 It Ci) v) aci 'tn L a O) a- O �O L a) 0 a) a 0 - a ° to O a ` to Y a a E a-0 E ;a C) CO 4= rnccaaa0 3EYo '= a) E . cc) cn - 03 ado •a_ ? EnCcao 0 w C to .r - O p)- 03 a Y CO O U � � C E N .cn O � 2 O L � co C L Y a, a a-0 _0 .- > � CO •- C I� '� E- ) O a_ •- . 3 0 N = -o U c cn a ` a a) a) C > 0 �_ a o o c`no c o •- c c = a- a N y a co a "- Y Qom - _ E � � o .o of a E � � Fh 3 a N a 0) - o � � c a J L a) 'a°) a = o 0 3 •ai 0) -o uN) E cm • a, nrMC = 0N c 0 - Y 0 c C • 0 L _ L - 0)0) a) (p O) E LL (� p CO H L U C m 0 vai j a) E co co p 0 - C 'd U O M O co C N _H o 'C 7 O C - m O a E E O V 0 O j •p a O En a co L N - N -c a"N Lo N 0 a a c a O N 0 N c o = O •� j (co �j a) c CD a Y -o Y_ a 3 O _M r = 'c -E• H 0 E 0 a Y 0 a s ,�, U N c m J Y . O ,-- °- 0 CO a 0 LL LEN s • 7 s_ = 0 .+ L N Y d U c O c 0 L (6 d Q L (o E N E• N a) 0-N N O N tri c E LO CO a) to > •- (o O C CI 3 3 0 OL m r o Lo _c -c L) o X . = U C a d 0 'a .c N c -0 0 O > :? >, c0i M a co oo o _ 3 •- .Srno - U •- a o m ▪ w s t stab—ft ao0 0 � - � 0 v co EL. (n E o 0.---. 0 ,,,,- _c)- > oi-- Ep` m a0 Y o ,- E n� o ami NI— E O 0 = O coo Lo ,_ 0) a •,7_ a� a o 0 0 0 -.coo c - - to 0 E 5 0 , a a c - 0 N 0 .Q on o F- � 0 co > S M 0 N O H O .= a O N c N ms (d in En a ca co o a) p I- o Lo a. a o N = a• 2 p 2 a (0 0 (n co as o c M • a c� ~ o o (a - m c - o) M 3 ▪ - to Z p N c'aa _c 3 •v O 0 j c v` o u CD to N co 0 •-inao -c c p0_ (n0 o U a) m0 0 $ to :a ,..r)� ° -0 0 W o c o Z @ O a 2 . L ci, _ .0 •`o 3 ) '—C2 Dl) o - 'u� a LL _ _o 'c •a-0 - E N L c 2 a � N N d M o ,•- -) O -C -0 *0 (n U � a N o Lo a a-_a O Cl) c) @N EN0 8 - L U _ E -a a0- (n O) ) aN cS c0) O 0• a 06) ,-- 0)C 5Q_ ofXMtI CO -C L .C-N ix) N 0- ONO 0-25 to a <6 ° (U u) _j N .c @ II - II C a uj-p ca (6 E O II 'E O L ' 0 U Z 0).._ � 0 a � iho � N (nC-, - OL_ o .0 0aL N = d � •co 0 m a) c E 3 .c � ami Ea �' � a � •n o c • s r O ° °) o N �N o m CD CO Q o c 3 0 x 0 3 rs 0 • N a c co .c 0 4[ o a a .0 O ao = -- 3 N H a vi 3 7 N ('"Do L 0 " Ua ca 0 .� a _ra „ E 0 U Y L 0 L -0 _ E _ U E• a) cco L C ,_ v tfao on co m 0j o) 2 •` E 0- 0 p Ta fab = Y N O "' N >, E c -oLC) E Ca 0 @ p (o p >, COCa 03 -a O a) N c_ L ,03 a0 •� -0 U c 00 D > �6 a 'cr - O 7 0 co c a) •- (o c O L " t]0 O C Y r O rn$ .N � 2201- 00 a) N U1J0- UL a UL_ 0_ i- 1HJ coY vs °3 E >• ‘-. 1- 042caE .0co ' D 2 ,- .- •,- - ,- N N N \�O ~ N N co CV (n Uj` \ co r N N N CrN N 0) 0) O) �J O) O) • i o c• Q-c ca To_ E v 0 v H o • LL co �_ •� o • Q Co ai o)) co_ o ui m 0) Co Col a T- L) O to N a' EO 0j co s? E 'x . 3c° N- c - vin ON c0 E Lt E Co co C- 3 a' co L 0- a' Q) ca O LL c O) O 'Q o > O 0 ul O _LO C o a- :E o o = ca o f .� oN _c coo o N 3 0 a) E C o _ co O M C a' Q- •- co_-o •� CO_gyp - o a) co Q � E) C7 o_ 'a a) v N c o_ m o o L c o .� Y 0 u' _a c' corn W M 0 F2 - 3o o •~ o ° vi o o m = N- o Et ai 0 'O a) - `- Co LL Co o a E > 7 3 w = N o a. •c E .0 0 u) ca r m ._ Q o � o� Y rn � �' O ai .0_ o c° w- o O 0 .... _e O O f'a) u_ 0 a H co o O ca .- 7 _ Y co E a' 2 O 0 O c -c - Co Ov 06- - T 0 7 d 0 N O O - 0 -0 o ".. 5 Y 0 O 0 o a) c rn o 2--4- o 0 3 i o _c 0 -o o rn t ' = o v cn a' "r.7) _c 0 0 O w o o C > O 0 - C O , o o)0 a) C O 0) O O O 3 o) 0 w b c 3 rn N Co CO c C) 00)I N (o n C a' C m 7 O O •E o •co_1E p` o c o0 •3 �o o j o o0)- 3 = o E C -, moo • c E O 0_.c Co •- ai o o in O .N- M t0 C o 9- 6 M > O •-O O 0 _C (D o) ai 'tet V O O 6j C co .E E 07:1,0 .� o E o c -O 3 0 CO v- o . cn-O O b O 0 C,- Q) _o O Co Cn _c 'C -0 v O C C p 0 CO M P = O O- JD .� co 'O I EE a) r= 'E 4 -0 C -- CO N •- CD O co CO 4 co N Co . o CO O 0 Q Co Y Co O 0_ E CO a) r 0 T O ,n c a O o Cb O Q C Q. 0 0 0 4- .9 E i .0 o O o co -0 22, v CO 3 3 0 CN- - o a)N- E o O ,- co O fl M C o c 0 cca o b 0 a' 9 o o 0 4- Co000 .. Co0 .0 co c C C) Lo co_ i- o co c C O 0 co 0_ a) Co a' co O a) o .- w .- �' a) a' -c 0 ..= -O O co O co O-Y Co 3• 0 N O.` U) 0 COO Q. •O C o t, 4-'03 cc o -aY _ = 03 • C I- mz E _�o .c'� rn � � o a) 3 00 LU0 0 a °' ct0a' cn • o @ ocn u) o ." o ctn' .- CO o O N E o a) 0. c in 0-•- _c a)- •crs 0 o o - o N o @ 0 0 0 .E 0 zT 0- 0 u) " c 0 0 _o Cr N- .� 0 0 c C Co o 2 v o = Y c o ui o • CC) a u) CO co Co o my o4- a) •Mo c o - boo 0TD O V) 0 -.- - M -0 O 3 .sO N E O CO • u) _o 3 � 0) - o o w o 3C �� o � 0 0QLU N = N C 0_ C ca E F- 2 00co- 0 O N Ca o O co E u) - u, c`') O o 0 0 C -- v 0 N EN0p) N O N in O 0) 10 '� Q -O -p 'D O W 0-o O 0_ L- .Q CO >• O - O O .- _ (6 0 M a) o C Co O O CO CO i C O a. C C V co or)� N .O O w O .- 2'co t c CC .- v- M c V -O 0_N 0 C (0 COo LL O C LO c- . O D I .t • a) a = 0) Co Q d _ o i 0 CO x 00 OTO N o C '- Co C CO o - a•,,,- E 0 c oo o 00 o o '� o x 0)7_ O O - O C,-O Co 0 Co C CO N c/) o I— - N N tr E a) M a) CO O C 0) o _C O p W 05 0 •L r c6 M C V C6 a) a 3 00 M@ c o °tf - op " o ¢ O io co N c.i O b r > LL O "E' -C N C E O a) O U -- i V t�O? O O O.. O '` O _C "- o Min .0 C c -C -o C H I- -a c W 0 0 0 3 3 c a-0 § u) 0 = 0 •-? 'E = . 2 7 o c o Q a io E ... 0 0 co cn 0) a w -o ,, a- o -o v a- �� _ • .` 0. ~ .E N O V' d- _c O Y •- p 0 > 'C 0 O Co a) 2 O •5 Co co 0- o v i� 0 3 0 'Q-.-• n- v) cn N . .� Q u) N MZ. u) N Q-0 0_ 0 M i - c_ 0 O a: , _c @ O _ O ED.0 _• O 0 0. 0-- uo) E m oc`' � M � _ > . � � M = \ � HCO 0 E Y Q•= > o 0 "c6 O .Q-•- C Co coo O co O M - 0 N O > O 0 co O o 3 .°W .0 M F -0 O` S F- 2i Co = m 0 a Co o 42 < I 0 2E N F- I O O o 0 N N N N CO 6) O ,- N N M ) 6) 6) • - "0 » beam a = b 7 ƒ - \ ••- & ) N- % k 0 /) � _ . _ � 00 0) \ \ \ ƒ / / / E ® = r ° % 2 £ a / 2 = = r 0) = n o # I % _ \ .g 0 » ° aCD dCO o 0 - ® a= ce = 0E 2 % § oz ® % o0 § I / 0 - r \ ® S $ / 12 oc # e - 0 - f \ g ? E \/ / a 2/e 7 - e- 3t I 0 o _ - _« a = r 0 LU• c\ G) > \ J / \ / . \ 50• 0 ¥ 7 a2 % 'Rx 2200 \ \ ^ - 7, » o U) I § _ ao © cr - Lo o .= » / .0 2 S_ - 0 ET� �69 "- o © © ° 0 ƒ / \ _ .• 0 % \ % 6 - 3e0 = 09a § .- \ 0 J & E 5 E c - = \& 04 £ / Rg = of \ / / \ � � 0 \ oo � \ = _ - = _c CO _ 2 s / � �_ = 3a e \ & n .gg = J = _ » _ 77 .$ \ « 3E § \ / 2m 6 / = 0 o0 - ± _ . \ 0 o -0 0 \ \ § f 2 a _ E \= E.@ &e = o ® 6 o � > & a m © \ G « � -0 _ _ = 0 2 = _ = a = # a ._ � w / }\ EU 2 ƒ z � _ \ & c ._ o o o \ \ \ / / C) \ \ U) 0 4- \ 0 # 4- ¥ _ \ 0-0 0 _ E .2.Z / \ 7 a '. \ ? 2 § R \ E4- r9 = § = = r = / � � e ¥ 2 ~ 0 OL ID' 5f 0 Co C f / ~ % 0 % 0 ® a 0 0 & J / 070 - o eO00 = g 2 e 0 2 N 0) Y s— § � o = o .. = o o - _ » & = o > = 4 = - (Ni® % o E_ / ° mezzo - 5 o 7777 = 00 � y /\ / \ / 0 \ ° 9 = 3 } / ®/ 2 0 .g g o > § .. - 0 2/ ® _ a \ ° 0) \ GJ/ ® k -- _ » A73C) / � � $ \ 0 _ Q \ O E \ / 0 7E/ \ \ / 0_#j \ 0 o /_0 0 0 / 0 -0 0 / -0 LO 2 \ 0 \ 0 0 0 E \ � ° tt 0) I- 5 7 5 �a . % R ° ° ® _ \ 0o 0. = Q = 0 - 2 = owo / 50 5 - £ - 00 = = R I # a _ x222 co $ / e 22 / r \ \ o \ o k \ \ /\ / 2 // / 0 co » . / 0 2 9 / l- . / E / / 0_ E /\ ® m / 4- 0 (00 . 0) 0 000 - > ) ® 0_ u•3 , = a_..= — « ° ', � # = S & ._ 5 £ ? ._ & so \ / \ /� � ° ° ° C ..5 _ (13 ƒ {/ £ b ¥ � &\ t - &\ 2 � ii ° ° = / / E / 7EK § w � o = ° = = c = a r i = = 0 / _ ,_ & a = o g < _ o == o CO _ » 6 i o \ < b \ oo = o » o = � 0) e - " E / 2722 \ » / / / $ N � ° Oe@ CO $ \/ \\ - . \\ _ - -- = Co CO e m t = 4 \ :- % / N 3 # co \ 0 § 0)2 / � I / 0 � II / f .5-0 0 o _.0 \ c c - S E _ II 0 II .c = = 6 ® e = e » stom _ = n 65 c._ . E _ S0 002 \ = \ \ / = - \ t \ 2 -- --0)' CO s@ == = ten = a ® 2a = © = � JG0 \ \gR\ E / R\ E \ \ J _ � � \ 0. } cu 777 0 \ ? 0 $ 0 ® % CO ® ? 0 CO 0 0 - / 2 0 0 = 0 (Cr] a ^ - ( oce = » = e # = 0) o # = oee2 = 2oz = .g \ / 7/ \ \ \ / \ # # N 0 0 \ 0 ƒ \ § § g \ co� � 33 ® aq /= � o\% / 2 > 0 ';- "E' in o = oro_= R S3S / E E - �o o o-oLE car :» RC0ro = $ k § $ \ CO 01 En 2 2 m w •- 0-\ - 3 2 \ R TD R 1 -).0 C = k t �p 2c 0- \ + _ � _ _ _ CO CO o § q \ 0FE2 E ° kOC e 0 ELE » = c ° -5-. £ /> o 0 To E° o = u �\_ C /f / oSo §o `- n E iri = § � $ ka 2 = � _ E� 0 a) « / ES % C c £ co o c _ 0 0 o co 7 _o \ _ 2 RRG & § co E E 13 E2 \s. \ - Co k3 \ gk m $ $ 0 c R _ _ ¥a fbf $ / / / 3 CL k ƒ k \ & = R = L E # o = � = 220ƒ 2 ƒ \ o a ) EDRF 03 i':5 t \ 2k ± g 3D 2 G = CI\of « 5 = E = Ecw0 � 2a § 5 G $ = 066 RS En M / & \ \ $ \ 7\ 0 _0 \ � c2 / \ - E CO \ = moor 2 $ I B ° = ac7 to n o 2 o10 &� © m 3 n � $ $k4- aS C *— 0 \ 2 f 2CEO 0 \ o / / ) § ® C - o - .- � &3 � 3 ® -C oCO- C'Jx \ � � CO CO2 0 f \ � � - c m \ = / oo \ % + 22 \ \ G cps 2 % 0 17 0 & ' < _c L Co O L Co < � � \ - 0@ k- a o_ .- ' a te .c% = � ± \ E \o / Ekofkof iiE co � S = 2o52r_ > a c0 \ \ k \ \ � 2Eq -- 2E � 2 22-0 q ± m 0 i , 2 , i , , i , Cl) m » 0-� k / � /$ \ \ ® f / \ 3 / kE '' 03 - Eco e E cc \ _ 0D1 = cc } irk } vim } Sfkk0 To 02fYo_ o_ = e # a < o « ar # c = eel # \ 0 • 2 § \ \/ // / 4 0 e o > \/ = _ = § +� \ } b § 2 5 = 1.0 \ / 2 ƒ 3 2 % / 0 \& <9 a) g © O) r \ \ z 5 * / \ 2 ^ oc _ .- ,- co E So os 5.-- 0_ / 0_ N \ � • _ .. E r o o ? 2 6 J 7 .g \ - O0 b •\ c \ \ E\ \ z_« aR ek ® a-a _ � O C \ / \ / \ -5f UOU CO � \ = m 7 E - $ % o 0 = 0 = E m 0. a) -0 0 0- b \ © ° ° 5 I as » a g § - ± 23 o / o22 ._ t3 0 co f \ . 4-- E § = \ o / co 2 - EU 0__ - m = 6 B. 7 '\\ § a t .0 ? 5 .® E § E 0 0 0 \CO \ 0 /J % ° b / \ o \ E e § \ \ - ® \ g . e = mE > 3 /\ EJ@ \ � 2 \ - co \ / / ° - \ 0 in'71-- c`i / \ 0 � \ \ \ r-- % � 7 \ \ \ O / / 2 / * E § / R % c m 0 \ ) R\ / ) E z J \ cE / = o = » _ C 2 0 / a k / \ 0 n 13 \ / \ \ \ o \ / \ _o \ ƒ 6® ± E e G \« 7 2 co c0 0) co o \ \ \ b b / © © k o / \ o R / \ a - . o e # # ® - c = = e = 9 = - k J 0 S = 0) w 7 0 « 6 0- _ = CO = CO• CO 0 CO E'CIS % CO ® % - 0 0 c 0 •- / E/S ~ \ - \ \ \ \ \ f \ / \ \ E / CO ƒ \ \ \ / 3 N— 0 ? / \ / 372 ® \ o % / . � UUe ± _ `- r = te .. .. 44 = _ _ = r < = 533 _C 2 CO �� ._ 4 e © b » o = _ �� ._ _ _ ii ._ ,- 9 w _o ° _ co a) of ° ° 27 » / 2 & zz . CD — u) .1- » otr b / & Eo © % k7 222 = 22 ® = E = © / _ E = © / - 2222 E= „ a = _3 � > 0E § EL ,, . ay= „ aii a = r \ _ e e \ 4 = 4 y = 7 7 > = g g o i c / S ~ \ 5 2 3 \ - _ � ? ^ ® a / _2 ® s \ / ° -o / -o g > . _ _ » o E = E / _ § f i n _ E = e = CO.) 6/ E \ 2 S 2 o m ° n = = o ® E N- i [ E h ~ / t -5 © 0 » ® = e CO m e I e o a o # _ _ _ = - R\ { 5 2 co 2 2 00 .. LU U-0- U / \ \\ \ \ \ 2 ,- § \ / a U# # / To U - o » a » � E = u # 6aIZIc2 » = o # EE < / � E = aaala # \ \ o o o 0 o C CO a) a) (6O C -0 Cl) N -0 CC o O 0 O 0 C 7 N O 0 c a) a) 0 (6 0 co a) co 91 U Cl) (6 o L C v) O O N so Q 0 O • CO m 0 a) co N J C a) -o co w 0 L CD CI. , Uj L E c) C c O Q N Lf) 0) To co C Lo• 0 co o o O Q O o = OU CO C CO C Q) CO 0 %` Cl) a) c (n m • 0 cn Er o Q o co O O m •-, o O 0)N a) 0) 0 O 'C - o•5 C L o_ L C = o 3 _o , O 0 as _a � o 10o Coo W • -0 -0 O L -0 0 0 C 0 .m O > CO = o o E — Co v • C o - o c 4 N ca CO -a O a) • O N C .-M O o .E U C - L MC E 0, O N O N 'N O (6 >,� O-O c Q 0 -0 Q L CO C -0 L N CO O C C co + r„, u) a) c c 'n N O _>'` 0 .N N E E o O �«- a) (>S 0- O cozio O 0) i• o2 L c o '- _ O- O 0') 0 Q 0 -O M a) p O coo Y C)) It 2 0 -0 N C 3 6j CD 0 w co Y o (o co u_ LO oN ` . CO (n Cfl (o -0 .«0) 0) (� L ..o •U _ .zr tea) o •- c Y o LO U — 0 c = a c = CLI � 0 ~ '20 a) r- -o 0)8 Oco 0 0) a) 0) co .L u) s M O E C 0 0)in = � O w a) = N (n (o O co N co o N O "t 0 m 0 oo 4_ _ O .(0 . o) Y Q o Y a) c _ • u) c O_ O o (6 ,- u) o 3CO c •- -C o Q E o 0 O c o w a) o O p CO 0 O- O— -0 -0 ',..,(-6 8' 0 0 0 O C -0 QCO C13 5 O .E CO• a) Lo C o CO O - C O o 0 0 0 CO 0 N I 4- ▪ O .5 0 0- i O L6 O O LO •(B U r m t V cr N O C p O o CO 0) a) 7 N CO -C 0 @ O O N O •• 7 O O O L .0 rnp) moo (—opo r L co = 0 3 = wrn o ` co _ w cn cfl i L = cn u) u)•= a o - -0 rn rn E CO L 6 (n v) Cl) 4) 2 d CO • ..0 COO a) _ .- L Cl) L 0 0) 0 ib a) O CO co O V) 9 o > o U II N M N 'o L O O U Q ta) 0 c)--c° M L 0 L > '� — IN - 0 in .N co y M O 2 O -C > -6a) N tr) LI� .in COIIO " ciNgopEc0 00 L. E 0_No -0 0 o .� N Lm (' Lso Qmo ON o0 ▪ -0 CO Q CO N O-CO '1 II C II N Cl) Ln Y _ 0) (6 Q.CO II CO II E N co Lf) 0 co '- N I I N N N u) E N ii I I L I I CO co ( 30 "-' p > O co u) N a) '= I I L I I co (a a) O N (n 0)CO N II \ Q E a) '6 Q -0 0)O E O CO coN .> II -E 0)-0 L -o o ' a) a) L E °O II 5 o II c E a) O a) C N E II 0 a) • CO -0 - Q a -O Q-O) 0 L TO Q) - o co -0 co -0 .o •E Q 0 >, 0 0 E p CO CO co a) 0 0) C 0 0 0 _C c -0 o Q S a) 0 o L CD _ C . 0 >II 0 co II 0)— (6 O (6 -s- Co E ` 1.Y E O W co II (B Co (4 0 CB U 00 nco 0cov EC3 C E 32 2H = I— UfY co Y uc) 0 � 0.. co -t E CHHI° = I° O 0 N N CO N- 0 O CO _ O < V N .O u) a Y C1� j > O .0 a CL 0)-° L O L u - 0 co 0 c 0 7 0 ? n = m 00 0 L C O c 0- ° E co > 3 a) 0)_ co 7 0-0 E 3 O C r "0 u) L a) 0 a) N U .c Op O p T a) C Y — 2 co CO -0 o n T c0) 'cLno ` N = C p _ 0 Ca . 0 (a -...- c U a j M p ° LL - O LL N c .� C7 O r- a 7 co p..._ M 00 o � C, a� c°°o a) @ is m m o •: 0 oNo 0 a>) ., o > - o 0 o M _o 'c O Z 0 O 0 Cn U L .- o .i- '0 7 CL- as :4- uiQ00 4 > u) co c0 _ U CO CC L E O N N 0 - •0 1 0) a C " n r- o -c 7 0 3 E0O ca c .c 2 mc� •c � � 4a o moc<.) L`nn °) E ca c`o N QEH w co o N N O �o nE a• v E ° o � nrn 0 nim o c a) o -° O co •t I • ca co u) 2 n Orn 7 •� 7Y -c 0 c 2) 0 .. Na0 Lo - aCLL coT ` n CO U 6 L Y co La ca L O CA co U O) N T CISo C 0 U O L L U O p p U C 000 ai C� a 0 3 a) 0 CO o o 0 0 •- 'CO n O a C7 v ca p C o m c`oo n .-o a>) �' coi n 0E CO a a) O N to U O co = ui = M E 2 co- @— �2 = LL L c u) eL 0 i� c m C Q O !o —O C) L a) O N H C 7 N- O U 0 a > M o = O Ca w (1 in .__CI) u) •- o) c M O j L p0 O >_ f6 u) 0 -0 -0 O T O O ,- L CD .O L c N L \ M T O N a) N j O 0 E •0 0_ 2 •C O Y >� °co ` O COO CO 7 C O I` H co O c oo . o > ° o Q@ L C co •y co . C co T O N O > CD 0 N LL I 3 O N O ° 'C O 0- 0- 7 C• T C) OM 0 d W CO Y 0 C L Z 7 T LO •c 0)-5 a C Ln 0. 10 c 0O o 'i a fl- N 2 T CO o n co 0 ° 0- 0 -E• ••='•C6 @ N C =0 0 f0 L N 0 i ` o T 2 E 0 .- C N E O 0 Ca O co 0 ` N d co Qoo Qp gi� " CRUX m cLn �c05 NN . °cn O � 0. LO aa) - co 0 00 o a s a) COCOS- 3 E z 0 0 7 o Ca CON- 0 O D ai c O CD-O O c0 a) 0 °-p_O •- 7 a CO 'CO C w C U _ Co Zi N 0 CV— d 0 N • O a) n 0 co 'O Ca U D O 0 7 L p 0 C6 0 0 - co c C la m 0)) N Ca a co a O (a 0 co uj Q"d n 0 L O a) N N O - T V 7 n N 0-0 n LO X N •C C v = C7 E o 6 u) ca. ° o f n 'c m U 0" E °) E Nt _ n T CIS _ YN 0 0 0 ° ° CO Lf) OO fa N 7 CD O C`a "' 0 02 p)O- Co-O COY co N- a) -O OV 0 2 N U 3 2• CV- N �;6 U c- a 'U � co 0 0 � C o � Co � -• E _c x" OY E 3 •m � 0 o ° E O .N � 0 m 0 L0 ch o c'> c 0 Y CL CO n a 0 — ui M CCU (a 0 a) aa)) Lc 0_ o O 7 O N O �, O Q (a _ (0 O 7 fa c d' 0)� b U = ca C ' - 0 0° '0. ca Z Zai ` rn ( u) CO -o = T ch U co ani 0- is c7) U 7 .co_.- 0E 3 a) >psU 0.s)= � � i6 L T • p 0 7 c '0 c . c T co _c ._ • > •3 • 0 U a°, _ ai u3) � 00a) oY r•-• +-- °: � •5 °�° Y � an N co C d CO000 LL 3 ° U LL C i 0 N '0 M O LL o T _ Cl) 0 E 0-13 m E 0 ' ca a' Co `- c c CD o a) CO ` •3 O. j 42 = Y n7 >S• Y E • Qornao caov Y o Q = 0 3Y a) o0 N a) C - 0 o c0 c C is 00 Ct Li" LOCD 1-4 0: 0 L pC H m 0 p •,- 7 - 7 N U') -00 L CI) o N Y 'O_ N 0 7 i a N CO lC) E T .0 •- 0• V) '0 .co00 O 7 0 0 - Ca 7 to OCA N 7 O ` 0 a o C 0O - c) "0 0 = n2 E Nor) 0 (-) 3 = T O 9 O N ? U p U > uj O T Y L '0 f0 C Y co O O (>0 ELL ,c CO > O• O OO CO @ CD 0 m COOO 0 0Ca OO C V 00LL 7 T c o -- L ` 3 O E CO Cl) O = 3 Cl) co Cl) u) LC) U -0 a O O 1E •5 ci Co Cl) u) 7 0 N co O` 0 u) ,Q in 7 0 7 0 0 u) 0 N o n.-. n T 0 3 E C N C a) •C II 000 II � NLO QUL 0 7L CDL CO n� .O OL a) C UT 0 C 7 CO •N T co •� op -0 C -0 c Y O U LCD co N O 0 Co — a 0 n 0 'D 7 U O E n T � E n O � r- 4 ' a) v• a 7 U n'�t '� � r j 0 N N v "- 0CD 0o W Z (.21- ..- n c 7 n ? , 2 Et. co E CO OOT MO es- co EO co v ° v E O o O � ° cO a L= ;_, U E C W NI- ° rn ✓ � ` o II co_ ` N II O n T N ca v_ 7 C� Ill 0033 N v� CO p 3 v N U) co O a) � •u) L S a) 3 CD N u) CO O CO N O Cl) N 0 II co a d O n H L II Y '0 a) II L H co .N C -0 V) N = co a Y II L II 00 CA N • II O N II E a) ' 0 c .0 O 3 > • L 0 0 • C 0 CO 0 C6 0 L 0) > > II U C 0 -0 V '° N O CO -o a a) N T 0 7 'O -o O) c 3 c.nn c 3 c c �_ E a O 0 x a) o a) a) E E n a)o co _o a) c µa ,> 3 3 _co 0 O a) •= p O E 0 "" O E O 0 7 0 ' O E 7,,,- h- Ca W ca ca cO LL a0' O co N La N Q O C O C •C c Ca N Ca 73 N 3 �T 72' 3 mT O p L N n� L N L N .N U • _O� LCL 4? 3 O N C0 co a L -CI L c CO II Co 3 :6 t6 T '0 O 7 '0 E E U U 7 vi �p ca 7 C p -0 W@ d vi p O U@ 7 m 0 0 , CO) 3 0 C`') n O O Ca T O Co O n O Ca 0 CO U 0 0 CCS O Ca O 0 •.- C > O -0 L ..- O Ca 0 O OLON E 7LIN E 7I- I- � Q2 > 2 n0HIH CO o CO XNI- 2H 00 ca Cl) . LL 0 CO OHIH Nr -ctT T T O O O O N N 0 op CD T O O O O T T • dU) _ a) N c f6 a) - ,, Y 0) C O -C (6 -0 >, •3 C 4# O O 7 0 _O CO C O 'C C 2 c (6 a) "O N ._-• u- •N u) LL 3 U (`6 s - N • 0 0 E c r .--- 0) ' f6 p) O O O a a N - so A O O 0• U •0 -00 '0 0 U N •_ 01 O CO 7 •7L O 0° C6 0°:CO 0 = O >, (7) O W N 0 Y CO L CO ° sT o � o Y w c .c (6 ° ai 7 N 0) an 7 Ch � .O I- a) N 2 Lc) • � 0 = C c 'rn a) > N n._ O O � gi eo O-. a) � a) c 0 7 co 7 � a) CT (s .O• •3 2 7 (6 O u) '$ ,- •cr o u) Op J -DE a 0- O N -0 O` 0E N C LL U ct _c = D i.40- i'CD cm•3 c L w, 0) v c E ° o 0 a ` 1 0-= 2 vs EY 0_ u) U `' O 70 u°, •co c o ,c rn C0 3 •- a v Y f6 �6 r (6 n ` a) c ° r 0 •?- ai a c c U E cc) CO- rn o N X,� 3 3 CD y•v o aO On a N -5 _cU • 3ox 3a6Eo ciE v7) = 3 _ 0Z 4- a •3 co - 0 7 p N N. (6 C C O_ 7 ° O EL w a@ c = LL U •C c "Q T N 2 -. E °-D Y 0 .0 0 .-• , 3 •-°p ° N •Q 0 3 2 2 0 ° U C to •0 ° H Y o 00 °o o�c a rn Q- m co 3 a) _0 VO' O m �7- 0 a) O 'C co t (6 "_' @ U N a- N c O •Q p _0 c (n N j) 0 77 ) 2 N � O 7 3 -1- m Nct E LL , •�U o m 0 C (s 0) a-iN O (6 �' _ v) N O rn O N ` 'C 'C @ (6 o2S C N U) .0 . ) O C 0_ O Y r D I-- -- U 'U 7 Ln '0 _c CO N O (6 U .O O@ ,C C p N ` 0 - CO N ,� V) U � Y z 0 p O N > U •O U N 7 O C N fl - . E D o n n ° 1- CL 3 .� •C Q rn ° co LLUU E _c o •O 0 -... 00 .2 U _o O � = 3 Y � .0-0 � 'O r N v E S,� N N 7 ° a6 o N co E _c •O C N °. N ° E co 0 7 a 7 •- '0 a) r _ (6 V n L O vi M C w a � a CO@ -0 c > 7 N V) a) a) -Y - �0 ,� � Y ._ f6 i .E _ --0 0) f6 C (6 a) _ �'Ln - `� - E 2- o_ '- c6 f6 'O ~ O co @ ?� a) Y_c 0 (j ('') ` 7 m a) �,'(j O t E LO �' a) co ` M N 0 7 0) a) •` N O NCO O c o_ as -15 a) O N > O O o 4O E N C c •N @ c U a C -0 N CO (6 O Q N >,I a) a O a so .: (s a) m 0 3 • Ccso... H2 � aC- Ca. a� � CO a0) E O - a) _0 � m00 ° 0_ I� U E Y a) _rn -O a) a) a) 0 (6 d N rn.` O CO i2 CO., u) Lo CCE 0 E 2 u) `o U rn 0 E U 5 a d Q- co in a) omo LL > Ud N = o 1- o n N C Cb Co 7 a 0 ` E N co O D)O - c 3 - C1) N 7 a c a E E o m s 0- U 0 o cn c ai '� C - •3 y .= o a) as C o ° in LUo m E L .' CU or`o oo > H _ C C o > rn 0) 7 2 Cb M u) o 0 U) .0 ((% O C •C O0 A a-CSO 0) (6 o_ E Y o 0 >,.g_ N co �° aE ° o � M a? v� (a 'o `� �E � - 0)- 0 c°)) (°oEQas - o Z eL 7 U Y u) CD CD C ui a) m O (co =er o 0 o 0 0 o m or E N c 3 Iii c E @ Y o t in ` N Y O Uj E o • Z' >:,, c o a) a) a) :a Q a r j -0 •` 0-•E °O0oa°i CO- `� mo owoo ` U0)� � CO• u) , 0 ,_ 3 - 0 0 0 2 > D o L u) 0 a) •as � -0 C a)r Y C ?0. C $ p • O a m CL>o C CD o 0 c w u' U (n a N a) CC n Cl- C p > = N C .0 ° C .E 3 '- c 75 n N d 0_ > OO E -O O (6 rOD '0 cL O ° UY 0- @ .Q pr N E 'C Or nN vEi in = ca ° a- -0O � cd ~ U "- N a) 1-L- (6 •CD ° co OM CL Oo 3 CCL I. 0- a) r E N o Q' 70 N OO 0) 0 y i6 `- U .° _- o a) n 13 © 0 7 0 7 0 Eflv, co — ,-,- CO ` .SI— CO CZ'ihvoEE _ a) .. mcEaEi OLn a) ° > Y 28 0)m m� - rn ` O = > oo O o nLL a) CO rna@0 � � 00 2 ° U a) c U ° N N ° C O (x6 U N 7 0 0 0 > • E 0- 2Z U (� a o m E ami a) o c o _ , a CP r3 //R�`` a) u) C7 m e o Y O n - .0 .% co L 0 LO Lo E ,C�, o C -D v ° C Y U ' 0 0 7 0 0 a N 0 d .Q m rn -0 a) a(6) c of >;H p= •= a = a) ~ 0 't N 0 (n c Q« n rn u) �o t :45 uu)i .T o nU .- O w in o U U 0 ao E rn El E _o c ° ` "-- U ° •0 (6 LL n a) Ln O co 0 O O (s 0 7 06 . E7 c O ie) 7 -•a a a) 0 U rn . 0 0 . <L a) m U E f6 co (6 V) o) Y co a) u) U) U) u- i 0 C N- U EY 7 LL 0 0i o L 7 Y M 1" -, a c i Y u7) .0 Y o '_ 7 a) p Y Q o Z . c '0- C7 nLi' 0 E H d ° (n ti 0)p (s 0 rn ° 0 C o C1 CC) a) 3 ` Y C '0 2 -- v) C O c) 0)r O O 0 . O •C co 0 a O E C f0 a) '` (6 -00 N 0 0 O ` O 5 V- • E N •- c c -O c - N r 'O u) a Q a C c N a) = (`�aasv14-ic > E .- Qoo c ca 6 5 r � .0LU .0 --5o Caa)) (`00, 3 -C a) Y c 2 E , a U Lri = Lf) - p C "0 4- C .U '3 U - ` a •5-@ U H NN .O2 C a m0)� O O -° 7 E O a) C -a 'c N c (°j - •' a)a) c - @ Q 3 p) c0 Cn r E O •C C N N t - 0 4 a) @ a) 0 3 (7s -0 p CTU a *Fs _ O . d N U .0 0)r C ° (Ns C Y o 3 m so N co a) m Y 0 ° fl--,- _ (Cs co C w 7 CO ° . _co Q 0> .c CO 7 M L U) .0 N _O iN V ° c CO N M 2 _0 N _O Ln ` O U -O 0 •-Ln N Ln c � 3 •C a) 0 7 � 4- o > N c 0 3000 > d � mo r • rY� 'C U � r cn co U -0 O v°i � � 03 C.0 O U 7 C .NN o (:) ,- 2 - -0 a) 0_O 2 r T ' in •3 C O o_ c 'O r c d m a) C 0) 7 O Ln 0 c p N a) N co 0 N Ln (L N o n o a) N N - > co O N N CA C 0) O U Q Ln 'Q II _o II -1 N = tp Q •- 2 -0 II (p II C• N o U 00 7 4? d II E II E E 0 ) C 2 II N U c 3 (A r - a 'O 2 � p_... U d -fi, O -0 Q -0 .� CD O CO � m U _0 .0 -0 7 O c a) _ 0 0 "0 Sp 'D O N C7 C) '0 76 = a) O N C E 0-CO N Q d c co a a 7 a) a s c' N N .0 N 0a W0 -c = a -o7 7O1ao(°) U) oCoE67p7 v N7EM.207or7a) ate) :oa°i707p7 U m a) CO C6 O m c/) 4- o o N m y o (6 i6 7 o c N (6 ra c C o v a� _c aVi .c 0_ o v ID 0)U m ° i6 -c 17 _c .5 3 a`� E vni N ° m _C c - o ._ - -C _c a •�c• YO p 3 0 7 (6 C N N ' O'N •_ U . O c6 7 c6 -. 0 .-- a) .O N (n 7 Ti t C c O = 2 0 7 (6 w O r r 0 +`•• 0 0@ O o E (s a.1- = _c O@ O o = (6 O M n a) @ O (6 0 0 •- C@ 0 O O O O 2 voMrr -oCnLnl- 21- U zz au) ,- U 7 UL. u) H21- U 3 a_aN C3)_c a) I- 2HU E E -0I- @�H21- 0 N N N N N co L T- r O O O O r r r a (1 a) -4- -a C c p o 0 a Q o idi p = co ) O (6 C o p c_ H 2 .E 0 _0 c 73 c C � Q a> C = 0 v> ( a) in r 0)a E no a) C a - E N ' C c .t C a) E o J ` �m � � EC) E 0C � . - o 3 3 a r d 0) 0 2 -o z,)CO 0 ws a) o - p N O, c N W - O fo a -p 'p o Y 3 ._Or - E g o. O O LL o Of4 NM N CL'- J 0) N O N- > w - N N -C 0Q_p O M a '5 O _0 COrO co p) _c ,_ 0 't Cp 2. iii Z O^ � v E o a) Y � ~ x `� � _a r -p N c O Bo fl-a p) a) p p ^CL (9 cu r Q O H. �O C W O O a) r O r p U O oco ` O LI • U C O U Q C '"- O C 3) Z a) L Q N U Q C co 0 �0 O x r i cL as C o � C U) O 9 -3 0 V O O O p 0 � 0 � o � M CD .5 _S) O l '' o 03 o n s ,e 0 co co co r 0 W 0 •— E o t O 0 U r E a o; 0 E - � o• ._ � Qor o EN 2 c Q• H p T Q_ _0 0 'Q CO N O c,4 ,_ c 5 o -C -CO 0 C.1) m73 amE � MN§ O -r_ nH = O .O -0 cV Cl) a C .o _ CO O i O3 - NQpO ' O CO eawp� cE fl o N � YU = taHZ% a) cu c6 Qu, O E p) " c_ Vi D • 0 3 VaDo 'c p a) _ QN U C - EN -0 o U - O iI- I C co 0 O 0 0 0o —O ct 0 3 ") o .Crn ULca) Q.(7) ) a 0 Cl- 0) E/i Q p '6 U o Q . o00 o � p0NTCO OQQa 17) CM� - -0 E CCS `n 3 c3E ,- 0 m 0 J � O OU aL U 3 0 _r -o Y o O Q 0 ,1-`o o co U _i c O r C 0C0 p N Q a) 'O U O p (7 C CO 0 LI) m• (Ni 7 C Q C -o o. N- E 0 C N 6)-o 2 0) C o H d U) 0 cn ca RS C = C o Q a) o (0 a r 0) '7 -C - -0 V) E CL C - a) co f.) - 3 m '� a) co Q CCo m a) o o)U) cr U) C 3O Q 3 C .- rte E - -'0-' u) 0 o O Q als N • ( op O�C > 3 S N c V c H o E 3 in Lr) - N a) _0 ai 00 a) 3 m .5 3 0 C w L. 0 U Q C N _ c ate) 0 0 0 N c 0 o O 3 WO co 7 c p E a) _p CO p N1:57p c c W ca o c o E U n3 73 = a) Cl.) U a) = o • Y0 E s m (o W .O r U = w a) C 2O o o a) 0 - T Y O CO 4) CO -p 3 o -o t N o c o .� ch a) Cl) Q U Q. Y o o c C ) 0 ca o f E p) E N o v) O 4) 0 Q 0- E v _ coin 0 � o � � � � D � 0E L- O \ co .x '� N E c6 c6 U U p O V D oo o r Q a`) o m 0- co = .E C 0 0 ¢ o Q •_ O C') U p i m O a) o U E ^ 0 in Q co .p 0 O V r -p m 3 0) N Q 0 c6 b - a) p -0 .3 _ a) CT) m r1. o o o E CO= a) E 0 0 r o tea) io o m � 000 LL 0 D u) N .E OU ( v „__co f4 N E J C _o 0. o -cS 03 5 6i 0 H a) -0 E 0 a) u, 0) -6 1- , F- x H c 7 a) .� CO O CO -o N 0_ co - 0) "" 7 0 ) r 3 c0 C w C ( •0 w v U a) cfl N 0 Um oo � -o LUN H 2 m cn a) co S p - 3 o m O a) co M N N O (o H p m o_ N ca °) cc 3 O a_ J o -ci a) O O u) c Com) a0) aL) o • �t v a0i o - O OZ O o 2 1 a a) T o E _ o __ O :� c co co Y N cf) r - coU U) H M = U) J 0_ d co o r U) .- 2. U) 0 W .E Q w 2 a) a a) .. . • #k 0 a) O ER 2 'a' v v v v' v v m _ tl u) Z r < _n ru E u_ D o 0 0 0 0 .,-- CD 0 Z O Q Z Q Q N N N N N N N = O () O N u') CO r a) c H O Q O C >_ N N co _ _ _ _ _ c Q (n U O o O r r r r r o _ > Q r co N• U O o = ✓ O "' 0 a_ 0 0 O7 2 .0 Q E (a n3 -O O Q O 0 CO C L • O a) ▪ a C Y Ca (a (a O p O Q O C O LU RS LU N b O (n p L Q � O 0 Y : O U Q D C C d O O a) O 0 Ca 0 C C) 0) .D C C C Q E O W (/) Qb ca C (0 0 U C O -Oa) C _ (a a) o J T CL CO c O C C O O 2 ca • c O - O C - O O 2 D O a) O-- U) a) p) O O _O O H C ((a m a) (n N a • O _c Q C C r N 0_ 0 •-(5- CO Q_ U C9 O O = H N O O co Z E 0 N co r Hilcorp Energy Company 0. Beaver Creek Unit Beaver Creek Unit BCU-24 I j 501332063900 Iii . Sperry Drilling Definitive Survey Report ort ill I ' 16 October, 2014 o 11 'n; Ie ri as t HALLUBURTON G�GI Sperry Drilling I Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Beaver CK Unit 24 Project: Beaver Creek Unit TVD Reference: Actual:BCU 24 @ 178.18usft((160.18 GL+18 KB)) ' Site: Beaver Creek Unit MD Reference: Actual:BCU 24 @ 178.18usft((160.18 GL+18 KB)) Well: Beaver CK Unit 24 North Reference: True Wellbore: BCU-24 Survey Calculation Method: Minimum Curvature Design: BCU-24 Database: Sperry EDM-NORTH US+CANADA Project Beaver Creek Unit Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Well Beaver CK Unit 24 Well Position +NI-S 0.00 usft Northing: 2,434,055.89 usft Latitude: 60°39'30.871 N +EI-W 0.00 usft Easting: 317,464.36 usft Longitude: 151°1'2.842 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: • 160.18 usft Wellbore BCU-24 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (0) (nT) BGGM2014 9/20/2014 16.93 73.63 55,442 Design BCU-24 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 18.00 Vertical Section: Depth From(TVD) +N/-S +El-W Direction (usft) (usft) (usft) (°) 18.00 0.00 0.00 133.76 Survey Program Date 10/16/2014 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 249.00 786.89 BCU 24 Rig Surveys(MWD+SC+sag)(B MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 09/10/2014 848.00 971.00 BCU 24 Rig Surveys(MWD_Interp Azi+s MWD_Interp Azi+sag Fixed:v2:std dec with interpolated azimuth+sag 09/24/2014 1,034.00 3,200.00 BCU 24 Surveys(MWD+SC+sag)(BCU- MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 09/24/2014 3,200.00 11,260.03 BCU 24 Surveys(MWD+SC+sag)(BCU- MWD+SC+sag Fixed:v2:standard dec&axial correction+sag 09/24/2014 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 18.00 0.00 0.00 18.00 -160.18 0.00 0.00 2,434,055.89 317,464.36 0.00 0.00 UNDEFINED 249.00 0.44 25.37 249.00 70.82 0.80 0.38 2,434,056.69 317,464.75 0.19 -0.28 MWD+SC+sag(1) 346.53 0.16 172.43 346.53 168.35 1.00 0.56 2,434,056.89 317,464.93 0.60 -0.29 MWD+SC+sag(1) 415.32 0.80 153.72 415.31 237.13 0.48 0.78 2,434,056.36 317,465.15 0.95 0.23 MWD+SC+sag(1) 475.78 1.44 139.46 475.76 297.58 -0.48 1.46 2,434,055.39 317,465.82 1.15 1.39 MWD+SC+sag(1) 539.80 2.47 139.81 539.74 361.56 -2.14 2.88 2,434,053.70 317,467.20 1.61 3.56 MWD+SC+sag(1) 602.52 3.57 137.38 602.38 424.20 -4.61 5.07 2,434,051.20 317,469.36 1.77 6.85 MWD+SC+sag(1) 663.27 4.65 139.93 662.97 484.79 -7.89 7.94 2,434,047.88 317,472.17 1.80 11.19 MWD+SC+sag(1) 723.00 5.78 137.19 722.45 544.27 -11.95 11.54 2,434,043.77 317,475.71 1.94 16.60 MWD+SC+sag(1) 786.89 8.06 131.57 785.87 607.69 -17.28 17.08 2,434,038.35 317,481.17 3.72 24.29 MWD+SC+sag(1) 848.00 10.27 134.16 846.20 668.02 -23.92 24.19 2,434,031.60 317,488.18 3.68 34.02 MWD InterpAzi+sag(2) 10/16/2014 5:35:14PM Page 2 COMPASS 5000.1 Build 70 Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Beaver CK Unit 24 Project: Beaver Creek Unit TVD Reference: Actual:BCU 24 @ 178.18usft((160.18 GL+18 KB)) Site: Beaver Creek Unit MD Reference: Actual:BCU 24 @ 178.18usft((160.18 GL+18 KB)) Well: Beaver CK Unit 24 North Reference: True Wellbore: BCU-24 Survey Calculation Method: Minimum Curvature Design: BCU-24 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) (0/100') (ft) Survey Tool Name 908.00 11.98 135.74 905.07 726.89 -32.11 32.38 2,434,023.29 317,496.23 2.89 45.59 MWD_InterpAzi+sag(2) 971.00 14.82 136.86 966.35 788.17 -42.67 42.45 2,434,012.57 317,506.14 4.53 60.17 MWD_Interp Azi+sag(2) 1,034.00 18.91 137.57 1,026.63 848.45 -56.09 54.85 2,433,998.96 317,518.34 6.50 78.41 MWD+SC+sag(3) 1,088.00 22.32 136.44 1,077.16 898.98 -69.98 67.83 2,433,984.87 317,531.09 6.36 97.39 MWD+SC+sag(3) 1,152.31 22.62 135.72 1,136.59 958.41 -87.69 84.88 2,433,966.90 317,547.87 0.63 121.95 MWD+SC+sag(3) 1,213.32 23.54 135.84 1,192.71 1,014.53 -104.83 101.56 2,433,949.50 317,564.28 1.51 145.85 MWD+SC+sag(3) 1,275.26 25.58 136.70 1,249.05 1,070.87 -123.43 119.35 2,433,930.62 317,581.78 3.34 171.57 MWD+SC+sag(3) 1,336.95 26.58 137.39 1,304.46 1,126.28 -143.28 137.82 2,433,910.49 317,599.95 1.69 198.64 MWD+SC+sag(3) 1,399.74 27.29 136.58 1,360.43 1,182.25 -164.08 157.23 2,433,889.40 317,619.03 1.27 227.04 MWD+SC+sag(3) 1,459.71 28.17 137.14 1,413.52 1,235.34 -184.44 176.31 2,433,868.74 317,637.79 1.53 254.90 MWD+SC+sag(3) 1,522.56 28.10 137.06 1,468.94 1,290.76 -206.15 196.48 2,433,846.72 317,657.63 0.13 284.49 MWD+SC+sag(3) 1,584.31 27.74 136.71 1,523.50 1,345.32 -227.26 216.24 2,433,825.31 317,677.06 0.64 313.36 MWD+SC+sag(3) 1,646.20 28.23 136.17 1,578.16 1,399.98 -248.30 236.26 2,433,803.96 317,696.74 0.89 342.37 MWD+SC+sag(3) 1,710.01 28.50 135.56 1,634.30 1,456.12 -270.06 257.37 2,433,781.88 317,717.51 0.62 372.66 MWD+SC+sag(3) 1,770.48 28.03 135.52 1,687.56 1,509.38 -290.50 277.42 2,433,761.13 317,737.25 0.78 401.29 MWD+SC+sag(3) 1,832.67 27.68 134.31 1,742.55 1,564.37 -311.01 298.00 2,433,740.30 317,757.51 1.07 430.34 MWD+SC+sag(3) 1,894.59 28.60 135.14 1,797.15 1,618.97 -331.57 318.74 2,433,719.43 317,777.93 1.61 459.53 MWD+SC+sag(3) 1,957.52 29.31 135.95 1,852.21 1,674.03 -353.31 340.08 2,433,697.35 317,798.93 1.29 489.98 MWD+SC+sag(3) 2,020.18 28.96 135.62 1,906.94 1,728.76 -375.18 361.35 2,433,675.16 317,819.86 0.61 520.47 MWD+SC+sag(3) 2,079.04 28.61 135.32 1,958.53 1,780.35 -395.38 381.23 2,433,654.65 317,839.42 0.64 548.80 MWD+SC+sag(3) 2,141.49 28.36 134.82 2,013.42 1,835.24 -416.47 402.26 2,433,633.24 317,860.13 0.55 578.58 MWD+SC+sag(3) 2,204.46 28.04 134.91 2,068.92 1,890.74 -437.46 423.35 2,433,611.93 317,880.89 0.51 608.33 MWD+SC+sag(3) 2,266.74 28.01 134.58 2,123.89 1,945.71 -458.06 444.14 2,433,591.01 317,901.35 0.25 637.59 MWD+SC+sag(3) 2,328.54 28.20 136.06 2,178.41 2,000.23 -478.76 464.60 2433,569.99 317,921.50 1.17 666.69 MWD+SC+sag(3) 2,390.57 28.08 136.47 2,233.11 2,054.93 -499.90 484.83 2,433,548.55 317,941.39 0.37 695.91 MWD+SC+sag(3) 2,452.58 27.91 136.15 2,287.86 2,109.68 -520.95 504.94 2,433,527.19 317,961.17 0.37 724.99 MWD+SC+sag(3) 2,514.80 28.64 135.95 2,342.66 2,164.48 -542.17 525.39 2,433,505.66 317,981.29 1.18 754.44 MWD+SC+sag(3) 2,575.86 28.78 136.12 2,396.21 2,218.03 -563.28 545.75 2,433,484.23 318,001.33 0.27 783.75 MWD+SC+sag(3) 2,639.19 28.37 135.79 2,451.82 2,273.64 -585.05 566.81 2,433,462.14 318,022.05 0.69 814.02 MWD+SC+sag(3) 2,701.38 27.88 135.48 2,506.67 2,328.49 -606.01 587.31 2,433,440.86 318,042.22 0.82 843.32 MWD+SC+sag(3) 2,763.73 28.78 135.60 2,561.55 2,383.37 -627.13 608.03 2,433,419.43 318,062.61 1.45 872.89 MWD+SC+sag(3) 2,825.80 29.35 135.37 2,615.81 2,437.63 -648.63 629.17 2,433,397.60 318,083.42 0.94 903.03 MWD+SC+sag(3) 2,887.50 29.11 135.83 2,669.65 2,491.47 -670.15 650.26 2,433,375.75 318,104.16 0.53 933.15 MWD+SC+sag(3) 2,948.55 28.60 135.19 2,723.12 2,544.94 -691.17 670.90 2,433,354.41 318,124.48 0.98 962.60 MWD+SC+sag(3) 3,010.50 28.23 134.14 2,777.61 2,599.43 -711.90 691.87 2,433,333.37 318,145.12 1.00 992.07 MWD+SC+sag(3) 3,071.94 28.13 136.28 2,831.77 2,653.59 -732.48 712.30 2,433,312.47 318,165.24 1.65 1,021.07 MWD+SC+sag(3) 3,134.55 28.03 137.93 2,887.01 2,708.83 -754.07 732.36 2,433,290.57 318,184.96 1.25 1,050.49 MWD+SC+sag(3) 3,152.71 27.62 137.33 2,903.07 2,724.89 -760.33 738.07 2,433,284.22 318,190.57 2.73 1,058.95 MWD+SC+sag(3) 3,197.07 28.42 136.32 2,942.23 2,764.05 -775.53 752.33 2,433,268.81 318,204.60 2.10 1,079.76 MWD+SC+sag(3) 3,261.18 28.79 135.87 2,998.51 2,820.33 -797.64 773.62 2,433,246.37 318,225.54 0.67 1,110.42 MWD+SC+sag(4) 10/16/2014 5:35'14PM Page 3 . COMPASS 5000.1 Build 70 Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Beaver CK Unit 24 Project: Beaver Creek Unit TVD Reference: Actual:BCU 24 @ 178.18usft((160.18 GL+18 KB)) Site: Beaver Creek Unit MD Reference: Actual:BCU 24 @ 178.18usft((160.18 GL+18 KB)) Well: Beaver CK Unit 24 North Reference: True Wellbore: BCU-24 Survey Calculation Method: Minimum Curvature Design: BCU-24 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 3,350.87 28.58 135.47 3,077.19 2,899.01 -828.44 803.70 2,433,215.11 318,255.14 0.32 1,153.45 MWD+SC+sag(4) 3,414.76 28.26 135.44 3,133.38 2,955.20 -850.11 825.03 2,433,193.11 318,276.13 0.50 1,183.84 MWD+SC+sag(4) 3,477.32 27.93 135.13 3,188.57 3,010.39 -871.05 845.76 2,433,171.86 318,296.53 0.58 1,213.29 MWD+SC+sag(4) 3,539.77 27.10 133.18 3,243.96 3,065.78 -891.15 866.45 2,433,151.44 318,316.91 1.96 1,242.14 MWD+SC+sag(4) 3,601.36 26.75 132.93 3,298.87 3,120.69 -910.19 886.83 2,433,132.08 318,336.99 0.60 1,270.03 MWD+SC+sag(4) 3,663.83 27.27 131.13 3,354.53 3,176.35 -929.18 907.90 2,433,112.77 318,357.77 1.55 1,298.38 MWD+SC+sag(4) 3,727.07 27.67 130.42 3,410.64 3,232.46 -948.23 930.00 2,433,093.38 318,379.56 0.82 1,327.51 MWD+SC+sag(4) 3,789.05 27.61 130.86 3,465.55 3,287.37 -966.95 951.81 2,433,074.32 318,401.09 0.34 1,356.22 MWD+SC+sag(4) 3,850.53 27.51 130.58 3,520.05 3,341.87 -985.51 973.37 2,433,055.43 318,422.36 0.27 1,384.63 MWD+SC+sag(4) 3,912.41 27.58 131.11 3,574.92 3,396.74 -1,004.23 995.02 2,433,036.38 318,443.71 0.41 1,413.21 MWD+SC+sag(4) 3,975.03 27.54 131.68 3,630.43 3,452.25 -1,023.38 1,016.75 2,433,016.89 318,465.15 0.43 1,442.16 MWD+SC+sag(4) 4,037.59 27.52 131.48 3,685.91 3,507.73 -1,042.57 1,038.39 2,432,997.37 318,486.48 0.15 1,471.05 MWD+SC+sag(4) 4,098.61 27.52 131.94 3,740.02 3,561.84 -1,061.33 1,059.43 2,432,978.28 318,507.24 0.35 1,499.23 MWD+SC+sag(4) 4,160.68 27.70 131.87 3,795.02 3,616.84 -1,080.55 1,080.84 2,432,958.74 318,528.34 0.29 1,527.98 MWD+SC+sag(4) 4,224.25 27.59 132.08 3,851.34 3,673.16 -1,100.27 1,102.77 2,432,938.68 318,549.97 0.23 1,557.46 MWD+SC+sag(4) 4,288.10 27.33 132.01 3,907.99 3,729.81 -1,119.99 1,124.64 2,432,918.62 318,571.52 0.41 1,586.89 MWD+SC+sag(4) 4,349.12 27.42 132.03 3,962.18 3,784.00 -1,138.77 1,145.48 2,432,899.52 318,592.07 0.15 1,614.94 MWD+SC+sag(4) 4,412.68 27.31 131.69 4,018.63 3,840.45 -1,158.27 1,167.24 2,432,879.69 318,613.53 0.30 1,644.14 MWD+SC+sag(4) 4,475.33 27.21 132.15 4,074.32 3,896.14 -1,177.44 1,188.59 2,432,860.19 318,634.58 0.37 1,672.82 MWD+SC+sag(4) 4,536.77 27.17 132.83 4,128.97 3,950.79 -1,196.40 1,209.29 2,432,840.91 318,654.99 0.51 1,700.88 MWD+SC+sag(4) 4,601.28 27.10 132.37 4,186.38 4,008.20 -1,216.32 1,230.95 2,432,820.66 318,676.33 0.34 1,730.30 MWD+SC+sag(4) 4,664.24 27.11 133.30 4,242.43 4,064.25 -1,235.82 1,251.99 2,432,800.84 318,697.06 0.67 1,758.98 MWD+SC+sag(4) 4,728.64 27.01 132.98 4,299.78 4,121.60 -1,255.85 1,273.36 2,432,780.47 318,718.13 0.27 1,788.28 MWD+SC+sag(4) 4,790.23 26.83 133.20 4,354.69 4,176.51 -1,274.90 1,293.73 2,432,761.11 318,738.19 0.33 1,816.16 MWD+SC+sag(4) 4,842.59 26.84 132.80 4,401.41 4,223.23 -1,291.02 1,311.01 2,432,744.73 318,755.23 0.35 1,839.79 MWD+SC+sag(4) 4,904.97 27.36 130.98 4,456.95 4,278.77 -1,309.99 1,332.17 2,432,725.43 318,776.09 1.57 1,868.19 MWD+SC+sag(4) 4,966.58 27.43 129.97 4,511.65 4,333.47 -1,328.39 1,353.73 2,432,706.70 318,797.36 0.76 1,896.49 MWD+SC+sag(4) 5,029.00 27.21 130.16 4,567.10 4,388.92 -1,346.83 1,375.66 2,432,687.92 318,819.00 0.38 1,925.08 MWD+SC+sag(4) 5,090.66 27.21 130.68 4,621.94 4,443.76 -1,365.11 1,397.12 2,432,669.31 318,840.18 0.39 1,953.23 MWD+SC+sag(4) 5,153.10 26.93 130.64 4,677.54 4,499.36 -1,383.63 1,418.68 2,432,650.47 318,861.45 0.45 1,981.60 MWD+SC+gag(4) 5,216.18 26.83 131.04 4,733.81 4,555.63 -1,402.28 1,440.25 2,432,631.49 318,882.73 0.33 2,010.08 MWD+SC+sag(4) 5,278.01 27.70 130.85 4,788.77 4,610.59 -1,420.84 1,461.65 2,432,612.59 318,903.84 1.41 2,038.37 MWD+SC+sag(4) 5,340.12 27.66 130.41 4,843.77 4,665.59 -1,439.63 1,483.54 2,432,593.47 318,925.44 0.34 2,067.18 MWD+SC+sag(4) 5,400.89 27.65 130.65 4,897.59 4,719.41 -1,457.96 1,504.98 2,432,574.81 318,946.59 0.18 2,095.34 MWD+SC+sag(4) 5,463.86 27.62 131.05 4,953.38 4,775.20 -1,477.06 1,527.08 2,432,555.37 318,968.39 0.30 2,124.51 MWD+SC+sag(4) 5,525.17 27.46 131.21 5,007.74 4,829.56 -1,495.71 1,548.43 2,432,536.39 318,989.45 0.29 2,152.83 MWD+SC+sag(4) 5,587.47 27.31 130.78 5,063.06 4,884.88 -1,514.50 1,570.06 2,432,517.26 319,010.78 0.40 2,181.45 MWD+SC+sag(4) 5,650.53 27.31 130.45 5,119.09 4,940.91 -1,533.34 1,592.02 2,432,498.09 319,032.45 0.24 2,210.34 MWD+SC+sag(4) 5,712.11 27.27 131.25 5,173.82 4,995.64 -1,551.81 1,613.38 2,432,479.29 319,053.52 0.60 2,238.54 MWD+SC+sag(4) 5,774.52 27.18 131.24 5,229.32 5,051.14 -1,570.63 1,634.84 2,432,460.14 319,074.69 0.14 2,267.06 MWD+SC+sag(4) 10/16/2014 5:35:14PM Page 4 COMPASS 5000.1 Build 70 • Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Beaver CK Unit 24 Project: Beaver Creek Unit TVD Reference: Actual:BCU 24 @ 178.18usft((160.18 GL+18 KB)) Site: Beaver Creek Unit MD Reference: Actual:BCU 24 @ 178.18usft((160.18 GL+18 KB)) Well: Beaver CK Unit 24 North Reference: True Wellbore: BCU-24 Survey Calculation Method: Minimum Curvature Design: BCU-24 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) (°) (usft) (usft) (usft) (usft) (ft) (ft) (0/100') (ft) Survey Tool Name 5,838.67 25.60 132.78 5,286.78 5,108.60 -1,589.70 1,656.03 2,432,440.74 319,095.59 2.68 2,295.56 MWD+SC+sag(4) 5,900.85 24.18 133.23 5,343.18 5,165.00 -1,607.55 1,675.17 2,432,422.60 319,114.45 2.30 2,321.73 MWD+SC+sag(4) 5,964.13 22.98 133.58 5,401.18 5,223.00 -1,624.94 1,693.57 2,432,404.93 319,132.57 1.91 2,347.04 MWD+SC+sag(4) 6,028.72 22.69 133.79 5,460.71 5,282.53 -1,642.25 1,711.69 2,432,387.33 319,150.42 0.47 2,372.11 MWD+SC+sag(4) 6,087.93 21.48 132.87 5,515.57 5,337.39 -1,657.53 1,727.88 2,432,371.81 319,166.37 2.13 2,394.37 MWD+SC+sag(4) 6,152.01 20.57 133.45 5,575.38 5,397.20 -1,673.26 1,744.65 2,432,355.83 319,182.90 1.46 2,417.35 MWD+SC+sag(4) 6,215.44 19.58 133.51 5,634.96 5,456.78 -1,688.24 1,760.45 2,432,340.60 319,198.47 1.56 2,439.13 MWD+SC+sag(4) 6,278.30 18.22 129.67 5,694.43 5,516.25 -1,701.76 1,775.66 2,432,326.84 319,213.46 2.93 2,459.46 MWD+SC+sag(4) 6,342.21 17.36 130.18 5,755.28 5,577.10 -1,714.29 1,790.63 2,432,314.08 319,228.24 1.37 2,478.94 MWD+SC+sag(4) 6,403.37 16.17 132.18 5,813.84 5,635.66 -1,725.90 1,803.91 2,432,302.27 319,241.34 2.16 2,496.57 MWD+SC+sag(4) 6,467.89 14.29 133.28 5,876.10 5,697.92 -1,737.39 1,816.37 2,432,290.59 319,253.62 2.95 2,513.51 MWD+SC+sag(4) 6,531.95 12.42 134.34 5,938.42 5,760.24 -1,747.63 1,827.05 2,432,280.19 319,264.14 2.94 2,528.31 MWD+SC+sag(4) 6,594.87 11.07 134.92 6,000.02 5,821.84 -1,756.62 1,836.17 2,432,271•.05 319,273.12 2.15 2,541.11 MWD+SC+sag(4) 6,659.55 9.92 133.48 6,063.62 5,885.44 -1,764.84 1,844.61 2,432,262.70 319,281.43 1.82 2,552.89 MWD+SC+sag(4) 6,721.63 8.92 134.04 6,124.86 5,946.68 -1,771.87 1,851.95 2,432,255.57 319,288.66 1.62 2,563.05 MWD+SC+sag(4) 6,782.56 7.53 133.85 6,185.16 6,006.98 -1,777.92 1,858.23 2,432,249.42 319,294.84 2.28 2,571.77 MWD+SC+sag(4) 6,842.26 6.01 133.15 6,244.45 6,066.27 -1,782.77 1,863.33 2,432,244.49 319,299.87 2.55 2,578.81 MWD+SC+sag(4) 6,908.99 5.88 133.63 6,310.82 6,132.64 -1,787.51 1,868.35 2,432,239.67 319,304.81 0.21 2,585.72 MWD+SC+sag(4) 6,971.13 5.78 133.83 6,372.63 6,194.45 -1,791.88 1,872.91 2,432,235.24 319,309.31 0.16 2,592.03 MWD+SC+sag(4) 7,032.66 5.84 134.15 6,433.85 6,255.67 -1,796.20 1,877.39 2,432,230.84 319,313.72 0.11 2,598.26 MWD+SC+sag(4) 7,094.16 5.37 132.06 6,495.05 6,316.87 -1,800.31 1,881.77 2,432,226.67 319,318.04 0.83 2,604.26 MWD+SC+sag(4) 7,156.55 5.20 134.67 6,557.18 6,379.00 -1,804.25 1,885.95 2,432,222.66 319,322.15 0.47 2,610.01 MWD+SC+sag(4) 7,218.17 4.98 133.59 6,618.56 6,440.38 -1,808.06 1,889.87 2,432,218.79 319,326.02 0.39 2,615.47 MWD+SC+sag(4) 7,280.83 4.74 133.05 6,680.99 6,502.81 -1,811.70 1,893.74 2,432,215.09 319,329.82 0.39 2,620.78 MWD+SC+sag(4) 7,342.55 4.79 135.32 6,742.50 6,564.32 -1,815.28 1,897.41 2,432,211.46 319,333.44 0.32 2,625.91 MWD+SC+sag(4) 7,403.69 4.59 136.32 6,803.43 6,625.25 -1,818.86 1,900.90 2,432,207.82 319,336.87 0.35 2,630.90 MWD+SC+sag(4) 7,465.00 4.40 135.07 6,864.55 6,686.37 -1,822.30 1,904.25 2,432,204.33 319,340.17 0.35 2,635.71 MWD+SC+sag(4) 7,533.12 4.99 132.81 6,932.45 6,754.27 -1,826.16 1,908.27 2,432,200.41 319,344.13 0.91 2,641.28 MWD+SC+sag(4) 7,594.73 4.90 133.23 6,993.83 6,815.65 -1,829.79 1,912.15 2,432,196.72 319,347.96 0.16 2,646.59 MWD+SC+sag(4) 7,656.48 4.83 133.61 7,055.35 6,877.17 -1,833.38 1,915.96 2,432,193.07 319,351.71 0.12 2,651.83 MWD+SC+sag(4) 7,717.13 4.62 132.93 7,115.80 6,937.62 -1,836.81 1,919.59 2,432,189.58 319,355.29 0.36 2,656.82 MWD+SC+sag(4) 7,779.82 4.55 132.02 7,178.29 7,000.11 -1,840.19 1,923.29 2,432,186.14 319,358.93 0.16 2,661.83 MWD+SC+sag(4) 7,842.19 4.54 132.84 7,240.46 7,062.28 -1,843.53 1,926.94 2,432,182.75 319,362.53 0.11 2,666.77 MWD+SC+sag(4) 7,901.86 4.95 131.97 7,299.93 7,121.75 -1,846.86 1,930.58 2,432,179.37 319,366.12 0.70 2,671.71 MWD+SC+sag(4) 7,965.27 4.87 129.84 7,363.10 7,184.92 -1,850.41 1,934.68 2,432,175.75 319,370.17 0.31 2,677.13 MWD+SC+sag(4) 8,027.62 4.81 131.25 7,425.23 7,247.05 -1,853.83 1,938.68 2,432,172.27 319,374.11 0.21 2,682.38 MWD+SC+sag(4) 8,088.46 4.79 131.01 7,485.86 7,307.68 -1,857.18 1,942.52 2,432,168.87 319,377.89 0.05 2,687.47 MWD+SC+sag(4) 8,152.03 4.81 133.59 7,549.21 7,371.03 -1,860.76 1,946.45 2,432,165.23 319,381.77 0.34 2,692.78 MWD+SC+sag(4) 8,214.46 3.97 131.17 7,611.45 7,433.27 -1,863.98 1,949.97 2,432,161.94 319,385.24 1.38 2,697.56 MWD+SC+sag(4) 8,277.71 2.89 131.68 7,674.59 7,496.41 -1,866.49 1,952.81 2,432,159.40 319,388.04 1.71 2,701.34 MWD+SC+sag(4) 10/16/2014 5:35..14PM Page 5 COMPASS 5000.1 Build 70 Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Beaver CK Unit 24 Project: Beaver Creek Unit TVD Reference: Actual:BCU 24 @ 178.18usft((160.18 GL+18 KB)) Site: Beaver Creek Unit MD Reference: Actual:BCU 24 @ 178.18usft((160.18 GL+18 KB)) Well: Beaver CK Unit 24 North Reference: True Wellbore: BCU-24 Survey Calculation Method: Minimum Curvature Design: BCU-24 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) (0/100') (ft) Survey Tool Name 8,338.83 1.54 143.07 7,735.66 7,557.48 -1,868.17 1,954.46 2,432,157.69 319,389.66 2.31 2,703.69 MWD+SC+sag(4) 8,399.88 0.29 199.37 7,796.70 7,618.52 -1,868.97 1,954.90 2,432,156.88 319,390.09 2.29 2,704.56 MWD+SC+sag(4) 8,461.15 0.28 239.36 7,857.97 7,679.79 -1,869.19 1,954.72 2,432,156.66 319,389.91 0.32 2,704.59 MWD+SC+sag(4) 8,521.59 0.32 243.23 7,918.41 7,740.23 -1,869.34 1,954.44 2,432,156.52 319,389.63 0.07 2,704.49 MWD+SC+sag(4) 8,584.16 0.29 246.88 7,980.98 7,802.80 -1,869.48 1,954.14 2,432,156.38 319,389.32 0.06 2,704.37 MWD+SC+sag(4) 8,645.21 0.46 254.23 8,042.03 7,863.85 -1,869.61 1,953.76 2,432,156.26 319,388.94 0.29 2,704.19 MWD+SC+sag(4) 8,707.71 0.44 242.05 8,104.53 7,926.35 -1,869.79 1,953.31 2,432,156.09 319,388.49 0.16 2,703.98 MWD+SC+sag(4) 8,770.10 0.53 263.76 8,166.91 7,988.73 -1,869.93 1,952.81 2,432,155.95 319,387.99 0.33 2,703.72 MWD+SC+sag(4) 8,833.70 0.62 273.64 8,230.51 8,052.33 -1,869.94 1,952.17 2,432,155.95 319,387.35 0.21 2,703.27 MWD+SC+sag(4) 8,896.20 0.31 245.47 8,293.01 8,114.83 -1,869.99 1,951.68 2,432,155.91 319,386.86 0.60 2,702.95 MWD+SC+sag(4) 8,957A6 0.49 250.01 8,354.27 8,176.09 -1,870.15 1,951.28 2,432,155.76 319,386.46 0.30 2,702.77 MWD+SC+sag(4) 9,020.40 0.35 245.57 8,417.21 8,239.03 -1,870.32 1,950.86 2,432,155.59 319,386.03 0.23 2,702.58 MWD+SC+sag(4) 9,083.02 0.49 252.86 8,479.82 8,301.64 -1,870.48 1,950.43 2,432,155.44 319,385.60 0.24 2,702.38 MWD+SC+sag(4) 9,145.70 0.50 244.30 8,542.50 8,364.32 -1,870.68 1,949.92 2,432,155.25 319,385.09 0.12 2,702.15 MWD+SC+sag(4) 9,206.59 0.42 255.54 8,603.39 8,425.21 -1,870.85 1,949.47 2,432,155.09 319,384.63 0.20 2,701.94 MWD+SC+sag(4) 9,268.63 0.40 265.37 8,665.43 8,487.25 -1,870.92 1,949.03 2,432,155.02 319,384.20 0.12 2,701.68 MWD+SC+sag(4) 9,331.10 0.65 283.83 8,727.90 8,549.72 -1,870.86 1,948.47 2,432,155.09 319,383.64 0.48 2,701.23 MWD+SC+sag(4) 9,392.57 0.69 287.11 8,789.36 8,611.18 -1,870.66 1,947.78 2,432,155.30 319,382.95 0.09 2,700.59 MWD+SC+sag(4) 9,454.80 0.41 301.45 8,851.59 8,673.41 -1,870.44 1,947.23 2,432,155.53 319,382.40 0.50 2,700.04 MWD+SC+sag(4) 9,517.29 0.65 310.37 8,914.08 8,735.90 -1,870.09 1,946.77 2,432,155.89 319,381.95 0.40 2,699.47 MWD+SC+sag(4) 9,578.53 0.73 316.51 8,975.31 8,797.13 -1,869.58 1,946.24 2,432,156.40 319,381.42 0.18 2,698.73 MWD+SC+sag(4) 9,641.69 0.60 295.45 9,038.47 8,860.29 -1,869.15 1,945.66 2,432,156.84 319,380.85 0.43 2,698.02 MWD+SC+sag(4) 9,703.89 0.65 319.57 9,100.66 8,922.48 -1,868.74 1,945.14 2,432,157.26 319,380.34 0.43 2,697.36 MWD+SC+sag(4) 9,765.83 0.45 301.94 9,162.60 8,984.42 -1,868.35 1,944.70 2,432,157.66 319,379.91 0.42 2,696.77 MWD+SC+sag(4) 9,828.02 0.59 314.36 9,224.79. 9,046.61 -1,867.99 1,944.27 2,432,158.02 319,379.48 0.29 2,696.21 MWD+SC+sag(4) 9,889.98 0.52 288.76 9,286.75 9,108.57 -1,867.68 1,943.77 2,432,158.34 319,378.99 0.41 2,695.64 MWD+SC+sag(4) 9,950.86 0.63 283.88 9,347.62 9,169.44 -1,867.51 1,943.19 2,432,158.52 319,378.40 0.20 2,695.10 MWD+SC+sag(4) 10,013.01 0.58 285.75 9,409.77 9,231.59 -1,867.34 1,942.55 2,432,158.70 319,377.77 0.09 2,694.52 MWD+SC+sag(4) 10,075.03 0.66 278.94 9,471.79 9,293.61 -1,867.20 1,941.90 2,432,158.85 319,377.12 0.18 2,693.95 MWD+SC+sag(4) 10,135.53 0.64 270.65 9,532.28 9,354.10 -1,867.14 1,941.22 2,432,158.92 319,376.44 0.16 2,693.42 MWD+SC+gag(4) 10,199.04 0.81 287.38 9,595.79 9,417.61 -1,867.01 1,940.43 2,432,159.07 319,375.66 0.42 2,692.76 MWD+SC+sag(4) 10,262.27 0.56 285.06 9,659.01 9,480.83 -1,866.79 1,939.71 2,432,159.29 319,374.94 0.40 2,692.09 MWD+SC+sag(4) 10,323.83 0.47 276.75 9,720.57 9,542.39 -1,866.68 1,939.17 2,432,159.41 319,374.40 0.19 2,691.62 MWD+SC+sag(4) 10,387.72 0.60 279.58 9,784.46 9,606.28 -1,866.60 1,938.58 2,432,159.51 319,373.81 0.21 2,691.14 MWD+SC+sag(4) 10,447.72 0.63 270.54 9,844.45 9,666.27 -1,866.54 1,937.94 2,432,159.57 319,373.17 0.17 2,690.64 MWD+SC+sag(4) 10,506.96 0.78 276.82 9,903.69 9,725.51 -1,866.49 1,937.21 2,432,159.63 319,372.44 0.28 2,690.08 MWD+SC+sag(4) 10,570.60 0.99 279.13 9,967.32 9,789.14 -1,866.35 1,936.24 2,432,159.79 319,371.47 0.33 2,689.28 MWD+SC+sag(4) 10,633.36 0.66 268.87 10,030.07 9,851.89 -1,866.27 1,935.34 2,432,159.88 319,370.58 0.57 2,688.57 MWD+SC+sag(4) 10,696.03 0.56 263.04 10,092.74 9,914.56 -1,866.32 1,934.68 2,432,159.85 319,369.91 0.19 2,688.12 MWD+SC+sag(4) 10,758.27 0.58 270.98 10,154.98 9,976.80 -1,866.35 1,934.06 2,432,159.82 319,369.29 0.13 2,687.70 MWD+SC+sag(4) 10/16/2014 5.35'14PM Page 6 COMPASS 5000.1 Build 70 Halliburton Definitive Survey Report Company: Hilcorp Energy Company Local Co-ordinate Reference: Well Beaver CK Unit 24 Project: Beaver Creek Unit TVD Reference: Actual:BCU 24 @ 178.18usft((160.18 GL+18 KB)) Site: Beaver Creek Unit MD Reference: Actual:BCU 24 @ 178.18usft((160.18 GL+18 KB)) Well: Beaver CK Unit 24 North Reference: True Wellbore: BCU-24 Survey Calculation Method: Minimum Curvature Design: BCU-24 Database: Sperry EDM-NORTH US+CANADA Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +El-W Northing fasting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 10,820.70 0.82 276.98 10,217.40 10,039.22 -1,866.29 1,933.30 2,432,159.90 319,368.54 0.40 2,687.11 MWD+SC+sag(4) 10,881.91 0.61 279.02 10,278.61 10,100.43 -1,866.19 1,932.54 2,432,160.01 319,367.78 0.35 2,686.49 MWD+SC+sag(4) 10,944.54 0.47 269.75 10,341.24 10,163.06 -1,866.13 1,931.96 2,432,160.07 319,367.20 0.26 2,686.03 MWD+SC+sag(4) 11,005.52 0.66 289.17 10,402.21 10,224.03 -1,866.02 1,931.37 2,432,160.20 319,366.62 0.44 2,685.53 MWD+SC+sag(4) 11,068.87 0.65 294.06 10,465.56 10,287.38 -1,865.75 1,930.70 2,432,160.47 319,365.95 0.09 2,684.86 MWD+SC+sag(4) 11,130.40 0.76 285.64 10,527.08 10,348.90 -1,865.50 1,929.99 2,432,160.74 319,365.24 0.25 2,684.18 MWD+SC+sag(4) 11,192.71 0.78 286.18 10,589.39 10,411.21 -1,865.27 1,929.19 2,432,160.98 319,364.44 0.03 2,683.44 MWD+SC+sag(4) 11,260.03 0.95 288.65 10,656.70 10,478.52 -1,864.97 1,928.22 2,432,161.30 319,363.47 0.26 2,682.52 MWD+SC+sag(4) 11,300.00 0.95 288.65 10,696.66 , 10,518.48 -1,864.75 1,927.59 2,432,161.52 , 319,362.85 0.00 2,681.92 PROJECTED to TD ,.. � " Checked By: Patrick Walker �.m.a, » m �� Approved By: CaryTaylor m.,. °, - Date: 10/16/2014 5:35:14PM Page 7 COMPASS 5000.1 Build 70 BCU-24 definitive survey H HEADER INFORMATION H COMPANY : Hilcorp Energy Company H FIELD : Beaver Creek Unit H SITE : Beaver Creek Unit H WELL : Beaver CK Unit 24 H WELLPATH: BCU-24 H DEPTHUNT: usft H SURVDATE: 10/16/2014 H H WELL INFORMATION H WELL EW MAP : 317464.36 H WELL NS MAP : 2434055.89 H DATUM ELEVN : 178.18 H VSECT ANGLE : 133.76 H VSECT NORTH : 0.00 H VSECT EAST : 0.00 H H SURVEY TYPE INFORMATION H 249.00 - 786.89 BCU 24 RIG SURVEYS (MWD+SC+SAG) : MWD+SC+SAG H 848.00 - 971.00 BCU 24 RIG SURVEYS (MWD_INTERP AZI+SAG) : MWD_INTERP AZI+SAG H 1034.00 - 3200.00 BCU 24 SURVEYS (MWD+SC+SAG) : MWD+SC+SAG H 3200.00 - 11260.03 BCU 24 SURVEYS (MWD+SC+SAG) : MWD+SC+SAG H H SURVEY LIST H MD INC AZI TVD NS EW 18.00 0.00 0.00 18.00 0.00 0.00 249.00 0.44 25.37 249.00 0.80 0.38 346. 53 0.16 172.43 346.53 1.00 0.56 415.32 0.80 153.72 415.31 0.48 0.78 475.78 1.44 139.46 475.76 -0.48 1.46 539.80 2.47 139.81 539.74 -2.14 2.88 602. 52 3. 57 137.38 602.38 -4.61 5.07 663.27 4.65 139.93 662.97 -7.89 7.94 723.00 5.78 137.19 722.45 -11.95 11.54 786.89 8.06 131. 57 785.87 -17.28 17.08 848.00 10.27 134.16 846.20 -23.92 24.19 908.00 11.98 135.74 905.07 -32.11 32.38 971.00 14.82 136.86 966.35 -42.67 42.45 1034.00 18.91 137. 57 1026.63 -56.09 54.85 1088.00 22.32 136.44 1077.16 -69.98 67.83 1152.31 22.62 135.72 1136. 59 -87.69 84.88 1213.32 23. 54 135.84 1192.71 -104.83 101.56 1275.26 25. 58 136.70 1249.05 -123.43 119.35 1336.95 26. 58 137.39 1304.46 -143.28 137.82 1399.74 27.29 136.58 1360.43 -164.08 157.23 1459.71 28.17 137.14 1413.52 -184.44 176.31 1522.56 28.10 137.06 1468.94 -206.15 196.48 1584.31 27.74 136.71 1523.50 -227.26 216.24 1646.20 28.23 136.17 1578.16 -248.30 236.26 1710.01 28. 50 135.56 1634.30 -270.06 257.37 1770.48 28.03 135.52 1687.56 -290.50 277.42 1832.67 27.68 134.31 1742.55 -311.01 298.00 1894.59 28.60 135.14 1797.15 -331.57 318.74 1957.52 29.31 135.95 1852.21 -353.31 340.08 2020.18 28.96 135.62 1906.94 -375.18 361.35 2079.04 28.61 135.32 1958.53 -395.38 381.23 2141.49 28.36 134.82 2013.42 -416.47 402.26 2204.46 28.04 134.91 2068.92 -437.46 423.35 2266.74 28.01 134.58 2123.89 -458.06 444.14 2328.54 28.20 136.06 2178.41 -478.76 464.60 2390.57 28.08 136.47 2233.11 -499.90 484.83 2452.58 27.91 136.15 2287.86 -520.95 504.94 2514.80 28.64 135.95 2342.66 -542.17 525.39 Page 1 BCU-24 definitive survey 2575.86 28.78 136.12 2396.21 -563.28 545.75 2639.19 28.37 135.79 2451.82 -585.05 566.81 2701.38 27.88 135.48 2506.67 -606.01 587.31 2763.73 28.78 135.60 2561.55 -627.13 608.03 2825.80 29.35 135.37 2615.81 -648.63 629.17 2887.50 29.11 135.83 2669.65 -670.15 650.26 2948.55 28.60 135.19 2723.12 -691.17 670.90 3010.50 28.23 134.14 2777.61 -711.90 691.87 3071.94 28.13 136.28 2831.77 -732.48 712.30 3134. 55 28.03 137.93 2887.01 -754.07 732.36 3152.71 27.62 137.33 2903.07 -760.33 738.07 3197.07 28.42 136.32 2942.23 -775. 53 752.33 3261.18 28.79 135.87 2998. 51 -797.64 773.62 3350.87 28. 58 135.47 3077.19 -828.44 803.70 3414.76 28.26 135.44 3133.38 -850.11 825.03 3477.32 27.93 135.13 3188. 57 -871.05 845.76 3539.77 27.10 133.18 3243.96 -891.15 866.45 3601.36 26.75 132.93 3298.87 -910.19 886.83 3663.83 27.27 131.13 3354. 53 -929.18 907.90 3727.07 27.67 130.42 3410.64 -948.23 930.00 3789.05 27.61 130.86 3465. 55 -966.95 951.81 3850.53 27.51 130. 58 3520.05 -985. 51 973.37 3912.41 27.58 131.11 3574.92 -1004.23 995.02 3975.03 27.54 131.68 3630.43 -1023.38 1016.75 4037.59 27.52 131.48 3685.91 -1042. 57 1038.39 4098.61 27.52 131.94 3740.02 -1061.33 1059.43 4160.68 27.70 131.87 3795.02 -1080. 55 1080.84 4224.25 27.59 132.08 3851.34 -1100.27 1102.77 4288.10 27.33 132.01 3907.99 -1119.99 1124.64 4349.12 27.42 132.03 3962.18 -1138.77 1145.48 4412.68 27.31 131.69 4018.63 -1158.27 1167.24 4475.33 27.21 132.15 4074.32 -1177.44 1188. 59 4536.77 27.17 132.83 4128.97 -1196.40 1209.29 4601.28 27.10 132.37 4186.38 -1216.32 1230.95 4664.24 27.11 133.30 4242.43 -1235.82 1251.99 4728.64 27.01 132.98 4299.78 -1255.85 1273.36 4790.23 26.83 133.20 4354.69 -1274.90 1293.73 4842.59 26.84 132.80 4401.41 -1291.02 1311.01 4904.97 27.36 130.98 4456.95 -1309.99 1332.17 4966.58 27.43 129.97 4511.65 -1328.39 1353.73 5029.00 27.21 130.16 4567.10 -1346.83 1375.66 5090.66 27.21 130.68 4621.94 -1365.11 1397.12 5153.10 26.93 130.64 4677. 54 -1383.63 1418.68 5216.18 26.83 131.04 4733.81 -1402.28 1440.25 5278.01 27.70 130.85 4788.77 -1420.84 1461.65 5340.12 27.66 130.41 4843.77 -1439.63 1483. 54 5400.89 27.65 130.65 4897.59 -1457.96 1504.98 5463.86 27.62 131.05 4953.38 -1477.06 1527.08 5525.17 27.46 131.21 5007.74 -1495.71 1548.43 5587.47 27.31 130.78 5063.06 -1514.50 1570.06 5650.53 27.31 130.45 5119.09 -1533.34 1592.02 5712.11 27.27 131.25 5173.82 -1551.81 1613.38 5774.52 27.18 131.24 5229.32 -1570.63 1634.84 5838.67 25.60 132.78 5286.78 -1589.70 1656.03 5900.85 24.18 133.23 5343.18 -1607. 55 1675.17 5964.13 22.98 133.58 5401.18 -1624.94 1693. 57 6028.72 22.69 133.79 5460.71 -1642.25 1711.69 6087.93 21.48 132.87 5515. 57 -1657. 53 1727.88 6152.01 20.57 133.45 5575.38 -1673.26 1744.65 6215.44 19.58 133.51 5634.96 -1688.24 1760.45 6278.30 18.22 129.67 5694.43 -1701.76 1775.66 6342.21 17.36 130.18 5755.28 -1714.29 1790.63 6403.37 16.17 132.18 5813.84 -1725.90 1803.91 Page 2 BCU-24 definitive survey 6467.89 14.29 133.28 5876.10 -1737.39 1816.37 6531.95 12.42 134.34 5938.42 -1747.63 1827.05 6594.87 11.07 134.92 6000.02 -1756.62 1836.17 6659. 55 9.92 133.48 6063.62 -1764.84 1844.61 6721.63 8.92 134.04 6124.86 -1771.87 1851.95 6782.56 7. 53 133.85 6185.16 -1777.92 1858.23 6842.26 6.01 133.15 6244.45 -1782.77 1863.33 6908.99 5.88 133.63 6310.82 -1787. 51 1868.35 6971.13 5.78 133.83 6372.63 -1791.88 1872.91 7032.66 5.84 134.15 6433.85 -1796.20 1877.39 7094.16 5.37 132.06 6495.05 -1800.31 1881.77 7156.55 5.20 134.67 6557.18 -1804.25 1885.95 7218.17 4.98 133.59 6618.56 -1808.06 1889.87 7280.83 4.74 133.05 6680.99 -1811.70 1893.74 7342.55 4.79 135.32 6742.50 -1815.28 1897.41 7403.69 4. 59 136.32 6803.43 -1818.86 1900.90 7465.00 4.40 135.07 6864.55 -1822.30 1904.25 7533.12 4.99 132.81 6932.45 -1826.16 1908.27 7594.73 4.90 133.23 6993.83 -1829.79 1912.15 7656.48 4.83 133.61 7055.35 -1833.38 1915.96 7717.13 4.62 132.93 7115.80 -1836.81 1919.59 7779.82 4.55 132.02 7178.29 -1840.19 1923.29 7842.19 4.54 132.84 7240.46 -1843.53 1926.94 7901.86 4.95 131.97 7299.93 -1846.86 1930. 58 7965.27 4.87 129.84 7363.10 -1850.41 1934.68 8027.62 4.81 131.25 7425.23 -1853.83 1938.68 8088.46 4.79 131.01 7485.86 -1857.18 1942. 52 8152.03 4.81 133.59 7549.21 -1860.76 1946.45 8214.46 3.97 131.17 7611.45 -1863.98 1949.97 8277.71 2.89 131.68 7674. 59 -1866.49 1952.81 8338.83 1. 54 143.07 7735.66 -1868.17 1954.46 8399.88 0.29 199.37 7796.70 -1868.97 1954.90 8461.15 0.28 239.36 7857.97 -1869.19 1954.72 8521.59 0.32 243.23 7918.41 -1869.34 1954.44 8584.16 0.29 246.88 7980.98 -1869.48 1954.14 8645.21 0.46 254.23 8042.03 -1869.61 1953.76 8707.71 0.44 242.05 8104.53 -1869.79 1953.31 8770.10 0.53 263.76 8166.91 -1869.93 1952.81 8833.70 0.62 273.64 8230. 51 -1869.94 1952.17 8896.20 0.31 245.47 8293.01 -1869.99 1951.68 8957.46 0.49 250.01 8354.27 -1870.15 1951.28 9020.40 0.35 245. 57 8417.21 -1870.32 1950.86 9083.02 0.49 252.86 8479.82 -1870.48 1950.43 9145.70 0.50 244.30 8542. 50 -1870.68 1949.92 9206.59 0.42 255.54 8603.39 -1870.85 1949.47 9268.63 0.40 265.37 8665.43 -1870.92 1949.03 9331.10 0.65 283.83 8727.90 -1870.86 1948.47 9392.57 0.69 287.11 8789.36 -1870.66 1947.78 9454.80 0.41 301.45 8851. 59 -1870.44 1947.23 9517.29 0.65 310.37 8914.08 -1870.09 1946.77 9578.53 0.73 316.51 8975.31 -1869.58 1946.24 9641.69 0.60 295.45 9038.47 -1869.15 1945.66 9703.89 0.65 319.57 9100.66 -1868.74 1945.14 9765.83 0.45 301.94 9162.60 -1868.35 1944.70 9828.02 0. 59 314.36 9224.79 -1867.99 1944.27 9889.98 0. 52 288.76 9286.75 -1867.68 1943.77 9950.86 0.63 283.88 9347.62 -1867. 51 1943.19 10013.01 0. 58 285.75 9409.77 -1867.34 1942.55 10075.03 0.66 278.94 9471.79 -1867.20 1941.90 10135.53 0.64 270.65 9532.28 -1867.14 1941.22 10199.04 0.81 287.38 9595.79 -1867.01 1940.43 10262.27 0.56 285.06 9659.01 -1866.79 1939.71 10323.83 0.47 276.75 9720.57 -1866.68 1939.17 Page 3 BCU-24 definitive survey 10387.72 0.60 279.58 9784.46 -1866.60 1938. 58 10447.72 0.63 270.54 9844.45 -1866.54 1937.94 10506.96 0.78 276.82 9903.69 -1866.49 1937.21 10570.60 0.99 279.13 9967.32 -1866.35 1936.24 10633.36 0.66 268.87 10030.07 -1866.27 1935.34 10696.03 0.56 263.04 10092.74 -1866.32 1934.68 10758.27 0.58 270.98 10154.98 -1866.35 1934.06 10820.70 0.82 276.98 10217.40 -1866.29 1933.30 10881.91 0.61 279.02 10278.61 -1866.19 1932. 54 10944. 54 0.47 269.75 10341.24 -1866.13 1931.96 11005. 52 0.66 289.17 10402.21 -1866.02 1931.37 11068.87 0.65 294.06 10465.56 -1865.75 1930.70 11130.40 0.76 285.64 10527.08 -1865.50 1929.99 . 11192.71 0.78 286.18 10589.39 -1865.27 1929.19 11260.03 0.95 288.65 10656.70 -1864.97 1928.22 11300.00 0.95 288.65 10696.66 -1864.75 1927. 59 Page 4 True Vertical Depth (2000 usft/in, 00 O O O O O O O O O O O m m o 0 o O O o 0 0 0 o O Y o_ o o 0 0 0 0 0 0 0 _ ? W a0 O N M l0 0 r W O ti } } I I 1 l I i I I l I I I I l I I I I l I I I I l I I I I l I I I 1 l I I 1 I I I I I I l I I I I l I I I I l I I I I l I J J cr coco o L O O 00 O—O O O - ..3- Z Z 2 - O 2 = = - N N Q 1- W W - ' C h m VOD co 1 - O = U b.J`o O VV_3 1 - Ih C7 Si - Y N N - / 0 C. W U00 CO / - N co O a188d `� / I - o >mmm / , —o cM W y .. ..E / O - N co LE 9"v a (337370? % / a- - CO 6 M i >Q Q. �, Z / CO.p, .,S5 '.?., U O /" O 03 G . C C C L N N E 0 coc 0 0 tt a�g - zN a'aa_ C N 0 O _ a) o Z> 0 •' co _ m W o m m v U _ 0 f ,,,g .."; ) `� a) O + > a10i —O • - o 0 —o O Cs) ii • / 0 N. / b VI . a. / ' N N / .7 / U = o (i) o cn - to CCN N D D w moD U c 000 - N N NNN 0 0 VI C) M a) a) a)U U ° + o0mmmm I a)f,-,• 0— L CL 5rn /An 0 3 O C o o-O•O p. N-o000 N U M r N 2 2.E 15'4765R 0 o c0,7„-,.... = Z Li .-Z 2y_Q� j 2 p ' O Li c d g 0 /n M F r 3 C MG ..<4 O Q o 0 aM o N I I �. (u►/gsn OS ) (+)ul-oNv(-)4;nos • Hilcorp Energy Company CASING&CEMENTING REPORT Lease&Well No BCU 24 Date 25-Sep-14 County Kenai Peninsula Borough State Alaska Supv Grubb/Sweetsir CASING RECORD TD 3200 00 Shoe Depth 3187 00 PBTD Casing(Or Liner)Detail Setting Depths I No of Jts Size Wt Grade THD Make Length Bottom Top Shoe 1 9 5/8 BTC Davis Lynch 1.90 3,187.00 3,185.14 2 jts 9 5/8 40 L-80 BTC 85.06 3,185.14 3,100.18 Flt Cr 9 5/8 BTC Davis Lynch 1.60 3,100.18 3,098.58 73 9 5/8 40 L-80 BTC 3,098.68 3,098.58 24.33 Pup it 9 5/8 40 L-80 BTC 3.12 24.33 21.21 Hanger 0.50 21.21 20.71 RKB 20.71 20.71 0.00 Csg Wt On Hook 130k Type Float Collar Davis Lynch No Hrs to Run 8 _ Csg Wt On Slips Type of Shoe Bull Nose Casing Crew WFD Fluid Description 9 5 Spud Mud Liner hanger Info(Make/Model) Liner top Packer? _Yes_No Liner hanger test pressure 3000 Centralizer Placement 1 centralizer on every other joint CEMENTING REPORT Preflush(Spacer) Type Mud Push II Density(ppg) 10 5 Volume pumped(BBLs) 40 Lead Slurry Type Lead Density(ppg) 12 Volume pumped(BBLs) 230 Mixing/Pumping Rate(bpm) 5 7 Tail Slurry Type Tail Density(ppg) 15 4 Volume pumped(BBLs) 20 Mixing/Pumping Rate(bpm) 5 N Post Flush(Spacer) m Type Density(ppg) Rate(bpm) Volume c v_ Displacement: Type 6%KCL Density(ppg) 8 32 Rate(bpm) 6 Volume(actual/calculated) 236/238 FCP(psi) 850 Pump used for disp Schlumberger Plug Bumped' Yes x No Bump press Casing Rotated? Yes x No Reciprocated? x Yes No 100%Returns during lob 100% Cement returns to surface? x Yes_No Spacer returns?Yes x No Vol to Surf 78 Cement In Place At 0 00 Date 9/25!2014 Estimated TOC Surface Method Used To Determine TOC Full Returns Preflush(Spacer) Type Density(ppg) Volume pumped(BBLs) Lead Slurry Type Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm) Tail Slurry w Type F Density(ppg) Volume pumped(BBLs) Mixing!Pumping Rate(bpm) N Post Flush(Spacer) 0 o Type Density(ppg) Rate(bpm) Volume w 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 CIW Type Serial No Size 16x11 W P 5000 Test Head To 250/5000 PSIG 15 MIN test good OK Remarks • • • • Hilcorp Energy Company CASING&CEMENTING REPORT Lease&Well No BCU 24 Date 14-Oct-14 County Kenai Peninsula Borough State Alaska Supv R Pederson/J Greco CASING RECORD TD 11300 00 Shoe Depth 11283 60 PBTD Casing(Or Liner)Detail Setting Depths No of Jts Size Wt Grade THD Make Length Bottom Top Shoe 5 1/2 Davis Lynch 1.68 11,283.55 11,281.87 2 jts 5 1/2 17 P-110 USS-CDC 89.23 11,281.87 11,192.64 Flt Clr 5 1/2 Davis Lynch 1.84 11,192.64 11,190.80 _ 185 jts 51/2 17 P-110 USS-CDC 8,176.33 3,057.01 11,146.36 Swell PKR 5 1/2 17 P-110 GeoCon 21.04 3,014.47 2,993.43 68 jts 5 1/2 17 P-110 USS-CDC 2,972.38 65.47 2,949.15 Pup Jt 2.30 21.05 18.75 Hanger 0.75 18.75 18.00 RKB 18.00 18.00 0.00 Csg Wt On Hook 179k Type Float Collar Davis Lynch No Hrs to Run 26 Csg Wt On Slips Type of Shoe Bull Nose Casing Crew WFD Fluid Descnption 6%KCUpolymer,PV14,YP 22 Liner hanger Info(Make/Model) Liner top Packer? Yes X No Liner hanger test pressure Centralizer Placement Ran total of 131 centralizers-1 centralizer on every joint,on 1st 89 its-1 centralizer on every other joint ,,,,..)j1 �� F/it 97 thru It 180 _ CEMENTING REPORT Preflush(Spacer) Type Mud Push II Density(ppg) 11 5 Volume pumped(BBLs) 35 t tAdb Lead Slurry ��rr�li ('_ Type Lead Zvi Density(ppg) Volume pumped(BBLs) Mixing/Pumping Rate(bpm) JJ Tall Slurry w Type Tail r'ei fp..j; Density(ppg) 15.3 Volume pumped(BBLs) 471 Mixing/Pumping Rate(bpm) 5 v N Post Flush(Spacer) � G O +Lw y Type Density(ppg) Rate(bpm) Volume V Displacement: Type 3%KCL Density(ppg) 8 5 Rate(bpm) 6 Volume(actual/calculated) 255/260 FCP(psi) 3450 Pump used for disp Schlumberger Plug Bumped? X Yes No Bump press 4000 Casing Rotated? Yes X No Reciprocated? X Yes_No 100%Returns dunng job 32% Cement returns to surface? Yes X No Spacer returns? Yes X No Vol to Surf 0 Cement In Place At 7 12 Date 10/15/2014 Estimated TOC 10,784 Method Used To Determine TOC Barrels pumped 471 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) ce Post Flush(Spacer) o 0 z Type Density(ppg) Rate(bpm) Volume NDisplacement: Type Density(ppg) Rate(bpm) Volume(actual/calculated) FCP(psi) Pump used for disp Plug Bumped? _Yes No Bump press Casing Rotated? Yes _No Reaprocated? _Yes_No %Returns during lob Cement returns to surface? Yes No Spacer returns? Yes No Vol to Surf Cement In Place At Date Estimated TOC Method Used To Determine TOC WELLHEAD Make CIW Type Serial No Size 16x11 W P 5000 Test Head To 250/5000 PSIG 15 MIN test good OK Remarks --_ ___ --_-- ^ a • NOON ^ / ‘ _...,,.,-. , , , ------, ',:,< \.--1.::/:\:',,,. -",• ._... -<.;-':- ' x ''''.1:.:,-. 1:, / l''''8' ' 6' ' ' 1' '''' ' .''''''''' \\ ± ~' . `` `` v • • 10 ft ii . '`,,,,,, ' , . ',,,, ,•'_,,,-,'''s,,:'z //i y \.. Illii i. '�}Ii t 1�I .z- , c �� r -1i. F ,tr E I , i i 1 � 't ''' 'klialaVallanffelklV:**Uto .,.. r o ki, i .-- -, _ ''' \ % \ S Ot\\ Y4 2 k cn _ �ll�pt� BCU 24 Days Vs Depth 0 -BCU 24 ACTUAL -BCU 24 Plan 2000 I\ \ 4000 t a 6000 a co co 8000 10000 12000 0 5 10 15 20 25 30 Days BCU 24 MW Vs Depth 0 - - 500ir - 1000 1500 2000 2500 3000 3500 4000 4500 MW vs Depth 5000 $ -BCU 24 Plan 5500 a a 0 a) 6000 a L 6500 7000 7500 8000 8500 9000 -- 9500 10000 10500 11000 11500 12000 8 9 10 11 12 13 14 Mud Density(ppg) Nolan Hilcorp Alaska, L, GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8308 ItiI itri, Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATE 11/10/14 To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 24 Elog data Prints: Reservoir Saturaton Tool Cement Evaluation Log CD: a Files Currently on the Disc (3) ;,1, Well Dlis 11x'4/2014 8:39 AM File folder Well Las 11x`4,12014 8:39 AM File folder „1, Well Log 11/4/2014 8:39 AM File folder Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: Nolan Hilcorp Alaska, L. GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8308 li�l.•nrp llnrku.I.IA, Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATE 11/06/14 To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 24 Elog data Prints: ROP Rate of Penetration, DGR Dual Gamma Ray, EWR-Phase 4, ALD Azimuthal Lithodensity, CTN Compensated Thermal Neutron MD DGR Dual Gamma Ray, EWR-Phase 4, ALD Azimuthal Lithodensity, CTN Compensated Thermal Neutron TVD CD: CGM 9/26/2014 1:44 PM File folder DLIS+LAS 9/26/2014 1:44 PM File folder EMF 9/26/2014 1:44 PM File folder PDF 9/26/2014 1:44 PM File folder TIFF 9/26/2014 1:44 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: Date: Nolan Hilcorp Alaska, L. GeoTech 3800 Centerpoint Drive Anchorage, AK 99503 Tele: 907 777-8308 'bleary.thi,Li.IJ.c. Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATE 11/06/2014 To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 24 Mudlog data Prints: End of Well Report 2" MD Formation Evaluation Log 5" MD Formation Evaluation Log 2" MD Gas Ratio Log 2" MD Drilling Engineering Log CD: Final Well Data a Files Currently on the Disc (5) , BEAVER CREEK UNIT 24 FINAL LOGS 10/28/2014 10:41 .,, File folder BEAVER CREEK UNIT 24 LAS EXPORTS 10/28/2014 10:41 .., File folder . EMF Log Viewer 10/28/2014 10:41 .,. File folder , Halliburton Log Viewer 10/28/2014 10:41 .,. File folder ®BEAVER CREEK UNIT 24 FINAL END OF W... PDF Document 6;798 KB 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: Date: A Nolan Hilcorp Alaska, L GeoTech 3800 Centerpoint Drive Anchorage, AK 99503 Tele: 907 777-8308 fllrnriUuxk:9.l.t.i. Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATE 11/03/2014 To: Alaska Oil & Gas Conservation Commission Meredith Guhl Petroleum Geology Assistant 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL 10 boxes: Dry Cuttings Transmitted herewith are cuttings from BCU 24 WELL SAMPLE INTERVAL BCU 24 3200'—3880' BCU 24 3880'—4800' BCU 24 4800'—5760' BCU 24 5760'—6680' BCU 24 6680'—7540' BCU 24 7540'—8280' BCU 24 8280'—9020' BCU 24 9020'—9860' BCU 24 9860'—10840' BCU 24 10840'—11300' 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: Date: 2.1 — 2 e%o ar\xi,rot 7�I it S"1'A, Alaska Oil and Gas � „ e LAsKA. Conservation Commission 333 West Seventh Avenue Anchorage,Alaska 99501-3572 [ i(11c-F,h,N( lit fill AI I FP Main:907.279.1433 �.� Fax:907.276.7542 ALAS www.aogcc.alaska.gov Stan Porhola Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: Beaver Creek Field,Undefined Tyonek Gas Pool, Beaver Creek 24 Sundry Number: 314-650 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, Cathy . Foerster Chair DATED this v day of December, 2014. Encl. RECEIVED • STATE OF ALASKA D E C 0 l2014 ALASKA OIL AND GAS CONSERVATION COMMISSION 03 -A APPLICATION FOR SUNDRY APPROVALS /'i sI zl V1 1 1— P-I ON 20 AAC 25.280 AOGCC 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod❑ Repair Well❑ Change Approved Program 0 Suspend❑ Plug Perforations❑., • Perforate❑., . Pull Tubing❑ Time Extension 0 Operations Shutdowi❑ Re-enter Susp.Wel ❑ Stimulate❑ Alter Casing Other.❑ 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to I)' Number Exploratory ❑ Development D 214-112 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,Alaska 99503 50-133-20639-00` 7.If perforating: 8.Well Name end Number. What Regulation or Conservation Order governs well spacing in this pool? 20AAC25.055fa)f4) LI Creek(BCU)24 Will planned perforations require a spacing exception? Yes ❑ No 9.Property Designation(Lease Number): 10.Field/Pool(s): A028083 ' Beaver Creek/Undef Tyonek Gas Pool • 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): 11,300 10,697 11,225 10,622 11,130 N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 70' 16" 70' 70' Surface 3,187' 9-5/8" 3,187' 2,933' 5,750 psi 3,090 psi Intermediate Production 11,284' 5-1/2" 11,284' 10,681' 10,640 psi 7,460 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(It): See Attached Schematic See Attached Schematic N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(t)and ND(ft): N/A;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 Stratigrephic❑ Development[r,f Service n 14.Estimated Date for 15.Well Status after proposed work: 12/05/14 Commencing Operations: Oil ❑ Gas p • WDSPL ❑ Suspended 0 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 Porhola Phone: 907-777-8412 Email sDorhola( hilcorD.corn Printed NameStan Porhola Title Operations Engineer Signature .4 _ Phone 907-777-8412Date (Z 11(11 COMMISSION USE ONLY / Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 3\. — COSI Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No EI Subsequent Form Required: (0 -'10'1 Approved by:aieki P 9)14.2(4,_, COMMISSIONER THE COMMISSION Date: /Z - �-I� APPROVED BY / z 1 I"( Submit Form and RBS �1o�ly� eyis�d tz ()Pie i 1 \ r�i or 12 rsi6nths from the date of approval Attachments in Duplicate L t 1 f.,>1` ,1 '7�y , y� 12..Z, y II Well Prognosis Well: BCU-24 Hi!corp Alaska,LL Date: 11/25/2014 Well Name: BCU-24 API Number: 50-133-20639-00 Current Status: Shut-In Gas Well Leg: N/A Estimated Start Date: December 4th, 2014 Rig: N/A Reg.Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-112 First Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Number: 1412278C Current Bottom Hole Pressure: —4,295 psi @ 10,527' TVD (Applied N2 press; No open perfs) Maximum Expected BHP: — 5,170 psi @ 10,357' TVD (Based on offset wells, EMW= 9.6ppg) Max. Allowable Surface Pressure: —4,134 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft) Brief Well Summary Beaver Creek Unit#24 was drilled as a Grass roots monobore completion in 2014 to target gas sands in the Sterling, Lower Beluga, and Tyonek formations.The initial zone perforated in the Tyonek in mid-November was non-productive. The purpose of this work/sundry is to perforate/plugback additional zones in the Tyonek. Notes Regarding Wellbore Condition • Well will be displaced with Nitrogen before initial perforating at+/- 3,400 psi SITP. 3,:-- E-line Procedure: ft— /2.-3-1-1 1. MIRU E-line, PT lubricator to 4,500 psi Hi 250 Low. a. Tree connection is 9.5" OTIS. b. SITP will be 3,400 psi (Nitrogen pressure). 2. RU 3-1/8" 6 spf Connex HC wireline guns. 3. RIH and perforate the following intervals: Zone Sands Top (MD) Btm (MD) FT SPF Tyonek T18 10,960' 10,970' 10' 6 Tyonek T10 10,452' 10,470' 28' 6 V Tyonek T3 10,018' 10,033' 15' 6 ✓ a. Bleed tubing pressure to 3,400 psi before perforating. b. Proposed perfs shown on the proposed schematic in red font. c. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. d. Correlate using Cement Bond Log (SCMT Log Dated 10/30/14). e. Use Gamma/CCL/to correlate. Utilize Press/Temp tool if available. f. Record tubing pressures before and after each perforating run. g. Proposed intervals are in the Undef Tyonek Gas Pool. h. Distance to nearest well open in same sands= No wells completed in Tyonek. . i. Spacing allowance is based on 20 AAC 25.055(a)(4); no wells within 3,000 ft. II : - Well Prognosis Well: BCU-24 Hilcorp Alaska,LL Date:11/25/2014 4. RD E-line. 5. Turn well over to production. E-line Procedure (Contingency): 6. If any zone produces sand and/or water. 7. MIRU E-line, PT lubricator to 4,500 psi Hi 250 Low. a. Tree connection is 9.5"OTIS. b. SITP will be+/-3,400 psi (remaining gas or applied Nitrogen pressure). 8. RIH and set 5-1/2" CIBP at depth above zone. Or 9. RIH and set 5-1/2" Casing Patch across the zone. Attachments: 1. Actual Schematic 2. Proposed Schematic BCU - 24 ACTUAL Pad 3 1,127 FNL, 1,645'FWL, SCHEMATIC Sec.34, T7N, R10W, S.M. Ilileorp Alaska. LI.( —_ Permit#: 214-112 Conductor 16" X-56 109 ppf API#: 50-133-20639-00 Tom Bottom Prop.Des: FED A-028083 :: +,t * MD 0' 70' KB elevation: 179.2' (18.6'AGL) .,y TVD 0' 70' Lat: N60° 39' 30.871" ..":1,, Long: W151° 1' 2.842" . Spud: 9/22/2014 16:00 hrs Surf8ce Casing TD: 10/09/2014 06:00 hrs ' s-5/e" L-80 40 ppf BTC 1' •1 -loe Bottom Rio Released: 10/16/2014 16:00 hrs 0. MD 0' 3,187' ND 0' 2,933' -� 1 12-1/4"hole Lead Cmt w/525 sks(230 bbls)of Tree cxn=9-1/2"Otis 12.0 ppg,Class G, Tail Cmt w/230 sks(50 bbls) 8.0"Seal Diameter .112T:2.-1015D/ f 15.4 ppg,Class G, 180 sks(78 bbls)to surface 5-1/8"Modified ID Bore Production Casing TOC(CBL 10/30/14)-2,584' 5-1/2" P-110 17 ppf CDC ' RA Mkr Jt 5,799' MD Top Bottom 0' 11,284' TVD 0' 10,681' 8-1/2"hole Cmt w/1,945sks(471 bbls)of 15.3 ppg, Class G colt w/EASYBLOK • RA Mkr Jt 7,948' Casing/Cementing Detail - 10.4 ppg Mud RA Mkr Jt 8,172' - 11.5 ppg Mud Push(35 bbl) - 15.3 ppg Cement(471 bbl) - 8.5 ppg 3%KCI(255 bbl) ' ••RA MkrJt 8,624' IRA MkrJt 8,934' • 4( 0 ":" RA Mkr Jt 9,825' Jewelry Depth • V J Fluid Level" 1.Swell Packer(21'Long) 2,993' •• _ ). 10,50 2.CIBP(Set 11/18/14) 11.130' I — RA MkrJt 10,837' . Perforations: Zone MD ND Size SPF Date Status Tyonek 11,170'-11,180'10,567'-10,577' 3-1/8" 6 11/16/14 Iso I • RA MkrJt 11,102' 2 Tyonek _ 1, Casing Shoe @ 11,284' Max Dogleg: 6.59°/100'@ 1,034' TD: PBTD: Max Inclination: 11,300'MD 11,225'MD 29.4°@ 2,826' 10,697'ND 10,622'ND Well Name&Number: Beaver Creek Unit#24 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska CountryIUSA Angle @KOP and Depth: 1.5°@ 500' _ Angle/Perfs:I N/A Maximum Deviation. 29.4°@ 2,826' Date Completed: 11/16/2014 Ground Level(above MSL): 160.6' RKB(above GL):, 18.6' Revised By: Stan Porhola Downhole Revision Date: 11/18/2014 Schematic Revision Date: 11/25/2014 . ., • BCU - 24 PROPOSED Pad 3 1,127 FNL, 1,645'FWL, SCHEMATIC Sec.34, T7N, R10W, S.M. Hilcorp Alaska,LLC Permit#: 214-112 Conductor ,'r 16" X-56 109 ppf API#: 50-133-20639-00 ' Top Bottom Prop.Des: FED A-028083 MD 0' 70' KB elevation: 179.2' (18.6'AGL) ND 0' 70' Lat: N60° 39' 30.871" • Long: W151° 1' 2.842" Spud: 9/22/2014 16:00 hrs Surface Casing TD: 10/09/2014 06:00 hrs 9.5/8" L-80 40 ppf BTC Rio Released: 10/16/2014 16:00 hrs . • Tom Bottom MD 0' 3,187' 1011115, ND 0' 2,933' • 1 12-1/4"hole Lead Cmt w/525 sks(230 bbls)of Tree cxn=9-1/2"Otis 12.0 ppg,Class G, Tail Cmt w/230 sks(50 bbls) 8.0"Seal Diameter of 15.4 ppg,Class G, 180 sks(78 bbls)to surface 5-1/8"Modified ID Bore ,t Production Casinq • TOC(CBL 10/30/14)-2,584' 5-1/2" P-110 17 ppf CDC Top Bottom RA MkrJt 5,799' MD 0' 11,284' ND 0' 10,681' 8-1/2"hole Cmt w/1,945sks(471 bbls)of 15.3 ppg, Class G cmt w/EASYBLOK ' RA Mkr Jt 7,948' Casing/Cementing Detail - 10.4 ppg Mud 'RA Mkr Jt 8,172' - 11.5 ppg Mud Push(35 bbl) - 15.3 ppg Cement(471 bbl) - 8.5 ppg 3%KCI(255 bbl) x ti ' RA Mkr Jt 8,624' RA Mkr Jt 8,934' i1 •' 0 ' ' RA Mkr Jt 9,825' Tyonek T3 v:, Jewelry Depth is 1.Swell Packer(21'Long) 2,993 Tyonek T10 _ r/ a RA Mkr Jt 10,837' Perforations: Zone MD ND Size SPF Date Status 4.CIBP(Set 11/18/14) 11,130' Tyonek T3 10,019-10,033' 9,415'-9,430 3-1/8" 6 Proposed 3 Tyonek T1010,452'-10,470' 9,849'-9,867 3-1/8" 6 Proposed Tyonek T1810,960'-10,970' 10,357-10,367 3-1/8" 6 Proposed - - Tyonek T20 11,170'-11,180'10,567'-10,577' 3-1/8" 6 11/16/14 Iso Tyonek T18_ RA Mkr Jt 11,102' 4 Tyonek T20 _ Casing Shoe @ 11,284' Max Dogleg: . ._ 6.59°/100'§1,034' TD: PBTD: Max Inclination: 11,300'MD 11,225'MD 29.4°@ 2,826' 10,697'ND 10,622'ND Well Name&Number: Beaver Creek Unit#24 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country:IUSA Angle @KOP and Depth: 1.5°@ 500' Angle/Perfs:I N/A Maximum Deviation. 29.4°@ 2,826' Date Completed. 11/16/2014 Ground Level(above MSL). 160.6' RKB(above GL): 18.6' Revised By. Stan Porhola Downhole Revision Date: Proposed Schematic Revision Date: 12/1/2014 OF T 2A-0.2.. 4s �_THE STATE zI,. Wirt:_=_-_ _ — :,33 v�es1 Se' en�r, A 'enue r'"= GOVERNOR SI AN PARN I:I-L Ancharcge, Alaska 99501-357;! QP-k,lunliS Stan Porhola Operations Engineer Hilcorp Alaska, LLC a, � 4.- 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Beaver Creek Field, Undefined Tyonek Gas Pool, BCU 24 Sundry Number: 314-598 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, ,O,, Daniel T. Seamount, Jr. Commissioner DATED this i 2 d�ay of November, 2014. Encl. a ` s-- M t- y l i.. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION `� r `"'1 p5 liq APPLICATION FOR SUNDRY APPROVALS ,, -,e'f Fes'- (" 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod❑ Repair WeII❑ Change Approved Program 0 Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing Time Extension❑ Operations Shutdowt❑ Re-enter Susp.Wel ❑ Stimulate❑ After Casing❑ Other. Drill shoetrack 0• / 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number. kt.Z cc— \ Exploratory ❑ Development ❑✓ • 214-112 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,Alaska 99503 50-133-20639-00• 7.If perforating: , jI�(2,5, ' -Xz.) 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? dr' 20AAC25.055(a)(4) Beaver Creek(BCU)24 • Will planned perforations require a spacing exception? Yes ❑ No Q /r./o-"r 9.Property Designation(Lease Number): 10.Field/Pool(s): A028083 • Beaver Creek/Undef Tyonek Gas Pool • 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): 11,300 10,697 11,191 10,588 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 70' 16" 70' 70' Surface 3,187' 9-5/8" 3,187' 2,933' 5,750 psi 3,090 psi Intermediate Production 11,284' 5-1/2" 11,284' 10,681' 10,640 psi 7,460 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(t)and ND(ft): N/A;N/A N/A;N/A 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch n Exploratory n Stratigraphic❑ Development n Service 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 11/11/14 - Oil ❑ Gas ❑✓ • WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date:101l/'-1 WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: ,L`, GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is`true and correct to the best of my knowledge. Contact Stan Porhola Phone: 907-777-8412 Email sDorhola( hilcorD.cortl Printed Name Stan Porhola Title Operations Engineer Signature _, 4-%-(._ Phone 907-777-8412 Date «// 0 '? ilt COMMISSION USE ONLY / Conditions of approval: Notify Commission so that a representative may witness Sundry Number. GT— Plug Integrity ❑ BOP Test [ Mechanical Integrity Test ❑ Location Clearance ❑ Other: -o If Sr ,,,n,_ /-S' %2 ( e'er/' Spacing Exception Required? Yes ❑ No [i Subsequent Form Required: / c-, —r1 C. (e2„, APPROVED BY Approved by: /�✓, COMMISSIONER THE COMMISSION Date. I 1 12,I ii 7(10, Submit Form and Form 10-403(Revised 10/2, 2) andlaG4tN I for 12 months froth th@approval. Attachments in Duplicate !NIS NOV 13 L ,ge et//07/4/ , ,:,) ,•0./, El . , s, Well Prognosis Well: BCU-24 llilcorp Alaska,LLi Date: 11/06/2014 Well Name: BCU-24 API Number: 50-133-20639-00 Current Status: New Grassroots Gas Well Leg: N/A Estimated Start Date: November 10th, 2014 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-112 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Number: 1412278C Current Bottom Hole Pressure: — 0 psi @ 10,587' TVD (No open perforations) Maximum Expected BHP: — 5,285 psi @ 10,587' TVD (Based on offset wells, EMW= 9.6ppg) Max. Allowable Surface Pressure: —4,226 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft) Brief Well Summary Beaver Creek Unit#24 was drilled as a Grass roots monobore completion in 2014 to target gas sands in the Sterling, Lower Beluga, and Tyonek formations. The purpose of this work/sundry is to drill out the shoe track to expose a sand in the Tyonek. Notes Regarding Wellbore Condition • Well filled with 3% KCI. Coiled Tubing Procedure: 1. MIRU Coiled Tubing, PT BOPE to 4,500 psi Hi 250 Low. 2. RU 2.00" coil. MU 4-5/8" mill and BHA. 3. RIH w/2.00" coil to 11,176' MD and tag top of unset cement. 4. Clean out unset cement to float collar at 11,191' MD. 5. Drill out shoe track from 11,191' to 11,211' MD. 6. Circ well clean. 7. Pressure up and test 5-1/2" casing to 3,000 psi for 30 min. Chart test. 8. POOH. LD 4-5/8" mill BHA. 9. MU 2.0"jet nozzle. 10. RIH w/2.00" coil and tag bottom at 11,211' MD. 11. Displace well fluids with Nitrogen. a. Estimated volume of displaced 3% KCI is 260 bbl. b. Measure starting and ending fluid volumes of flowback tank. 12. Leave well with 3,500 psi Nitrogen SITP. 13. POOH w/coil. 14. RD Coiled Tubing. 15. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic 3. BOPE Schematic BCU - 24 ACTUAL Pad 3 1,127 FNL, 1,645'FWL, SCHEMATIC Sec. 34, T7N, R10W, S.M. Ililr•orp Alaska. LLC Conductor Permit#: 214-112 16" X-56 109 ppf API#: 50-133-20639-00Tom Bottom Prop.Des: FED A-028083 MD 0' 70' KB elevation: 179.2' (18.6'AGL) TVD 0' 70' Lat: N60° 39' 30.871" Long: W151° 1' 2.842" Spud: 9/22/2014 16:00 hrs 4 Surface Casinq TD: 10/09/2014 06.00 hrs 9-5/8" L-80 40 ppf BTC i;:'1 Lap Bottom Rio Released: 10/16/2014 16:00 hrs MD 0' 3,187' ,4t-- TVD 0' 2,933' T--- 1 12-1/4"hole Lead Cmt w/525 sks(230 bbls)of Tree cxn=9-1/2"Otis rw; 12.0 ppg,Class G, Tail Cmt w/230 sks(50 bbls) 8.0"Seal Diameter of 15.4 ppg,Class G, 180 sks(78 bbls)to surface / 5-1/8"Modified ID Bore ° • • Production Casing TOC(EST)-2,800' _-- 5-1/2" P-110 17 ppf CDC I : Top Bottom RA MkrJt 5,799' MD 0' 11,284' ND 0' 10,681' • 8-1/2"hole Cmt w/1,945sks(471 bbls)of 15.3 ppg, Class G cmt w/EASYBLOK ••RA Mkr Jt 7,948' Casing/Cementing Detail - 10.4 ppg Mud RA Mkr Jt 8,172' - 11.5 ppg Mud Push(35 bbl) - 15.3 ppg Cement(471 bbl) - 8.5 ppg 3%KCI(255 bbl) 1 RA Mkr Jt 8,624' ' RA Mkr Jt 8,934' • ' T RA MkrJt 9,825' Jewelry Depth 1.Swell Packer(21'Long) 2,993' IRA MkrJt 10,837' • Perforations: Zone MD TVD Size SPF Date Status .d RA Mkr Jt 11,102' �• W 1 Tag(unset cement)@ 11,176'SLM _ y Casing Shoe @ 11,284' Dr r(1 Max Dogleg: w/4.53"GR(10/21/14) - --- I(Z- (Z`l ' 6.59°/100'@ 1,034' TD: PBTD: Max Inclination: 11,300'MD 11,191'MD 10,697'TVD 10,588'TVD 29.4°@ 2,826' Well Name 8 Number_ Beaver Creek Unit#24 _ Lease. A-028083 County or Parish. Kenai Peninsula Borough State/Prov: Alaska _ Country:IUSA Angle @KOP and Depth:- 1.5°@ 500' Angle/Perfs:I N/A Maximum Deviation: 29.4°@ 2,826' Date Completed. N/A Ground Level(above MSL). 160.6' RKB(above GL): 18.6' • Revised By: Stan Porhola Downhole Revision Date. 10/21/2014 Schematic Revision Date: 10/27/2014 .. .. . BCU - 24 PROPOSED Pad 3 1,127 FNL, 1,645'FWL, SCHEMATIC Sec.34, T7N, R10W, S.M. IIiI.•urp Alaska. I.1.(: Permit#: 214-112 Conductor •API#: 50-133-20639-00 16" X-56 109 ppf Top Bottom Prop.Des: FED A-028083 MD 0' 70' KB elevation: 179.2' (18.6'AGL) TVD 0' 70' Lat: N60° 39' 30.871" Long: W151° 1' 2.842" Spud: 9/22/2014 16:00 hrs Surface Casing TD: 10/09/2014 06:00 hrs 9-5/8" L-80 40 ppf BTC Rig Released: 10/16/2014 16:00 hrs 1:.p Bottom . MD 0' 3,187' >!r. 1,* TVD 0' 2,933' -- 1 12-1/4"hole Lead Cmt w/525 sks(230 bbls)of Tree cxn=9-1/2"Otis ' '. 12.0 ppg,Class G, Tail Cmt w/230 sks(50 bbls) 8.0"Seal Diameter i' +, of 15.4 ppg,Class G, 180 sks(78 bbls)to surface 5-1/8"Modified ID Bore ' TOC(CBL 10/30/14)-2,584' Production Casing 5-1/2" P-110 17 ppf CDC Top Bottom RA MkrJt 5,799' MD 0' 11,284' ND 0' 10,681' 8-1/2"hole Cmt w/1,945sks(471 bbls)of 15.3 ppg, ti Class G cmt w/EASYBLOK RA Mkr Jt 7,948' �n i, � Casing/Cementing Detail - 10.4 ppg Mud RA MkrJt 8,172' - 11.5 ppg Mud Push(35 bbl) ... d" - 15.3 ppg Cement(471 bbl) ..g - 8.5 ppg 3%KCI(255 bbl) RA Mkr Jt 8,624' RA Mkr Jt 8,934' RA Mkr Jt 9,825' Jewelry Depth 1_Swell Packer(21'Long) 2,993' RA MkrJt 10,837' Perforations: Zone MD TVD Size SPF Date Status ••RA MkrJt 11,102' Drill out 20'of shoe track Casing Shoe @11,284' Max Dogleg: from 11,191'to 11,211'MD . - 6.59°/100'@ 1,034' TD: PB ID: Max Inclination: 11,300'MD 11,211'MD 10,697'ND 0 608'Nn 29.4°@ 2,826' Well Name&Number: Beaver Creek Unit#24 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska _ Country:IUSA Angle @KOP and Depth. 1.5°@ 500' Angle/Pers.I N/A Maximum Deviation. 29.4°@ 2,826' Date Completed: N/A Ground Level(above MSL) _ 160.6' RKB(above GL): 18.6' Revised By: Stan Porhola Downhole Revision Date. Proposed Schematic Revision Date. 11/6/2014 Beaver Creek Unit BCU #24 11/07/2014 Meal? Ia&a.I.1A: Beaver Creek#24 16X95/8X5'A Coil Tubing BOP Lubricator to injection head U 0 Ifni) 2"Tandem Stripper 1 I I 0.1.111ME ' 1/1615 /1615 _ ,,,,,.1 I n cor.mom * !!_ _ul.i1 Fiui ' E !IuIuFt 111111.111110- Eli-M111114 Mud Cross 1 m— •. : / - 4 1/16 15M X 4 1/16 10M Ilil �� 11� �.M \Q1�ill�I� 1���� Outlet �- I? am • .I - - w/2 2 1/16 15M full HCR HCR opening plug valves 2 1/16 15M 18 a 2 1/16 15M Crossover spool r 4 1/16 10M X5 1/8 5M a- •d WI mL CJ o1'' 4) •N Wing, CIW-FLS-R, � Y� 3 1/8 5M, DD trim .il,•W,r Valve rated to 5000psi Tree assy, CIW-FLS-R, 5 1/8 5M, DD trim C N //d I ! I w/61/2"Otis top a ( (!�li4` 0 Swab/Upper Master • - Valves rated to 5000psi - �1 n r. SSV,31/85M ���' `': Valve rated to 5000psi 0.•1.1m Or Lower Master, ,� , I CIW-FLS-R, OA* 5 1/8 10M, DD trim ,.,Y.,, Valve rated to 10,000psi 1, 1 C . 7.._11 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Tuesday, November 11, 2014 8:49 AM To: 'Chad Helgeson' Cc: Cole Bartlewski - (C) Subject: RE: BCU 24 CTU drillout. (PTD 214-112) Chad, You have verbal approval to proceed as per the submitted sundry. You can send notice today for CT BOP test witness. Regards, 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: Chad Helgeson [mailto:chelgeson@hilcorp.com] Sent: Tuesday, November 11, 2014 7:04 AM To: Schwartz, Guy L(DOA) Cc: Cole Bartlewski - (C) Subject: RE: BCU 24 CTU drillout. (PTD 214-112) Guy, Thanks, Do you have a problem with us making notice today for BOP test tomorrow and start the work tomorrow? Chad From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Monday, November 10, 2014 5:00 PM To: Chad Helgeson; Stan Porhola Subject: BCU 24 CTU drillout. (PTD 214-112) Have the sundry and have reviewed it. Should be ready Wednesday... 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 1 2,Lk. \\Z II Seth Nolan Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8308 z50`-t9 rr;ir„rp tia.r.a_r.r 1RECEIVED Fax: 907 777-8510 E-mail: snolan@hilcorp.com NOI 14 2014 DATA ti i1°LOGGED NI.K.BENDER DATE 11/10/14 AOGCC To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL BCU 24 Elog data Prints: Reservoir Saturaton Tool Cement Evaluation Log CD: . • =iies Currently (3) on the Disc ,'tell Dlis 11/4/2014 8:39 AM File folder ';'.ell Las 1114/2014 8:39 AM File folder ;':ell Log 11,'41200148:39AM 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:p')/4,247.40...„ / Date: i ,, ,,,,_,,, II Seth Nolan Hilcorp Alaska, LLC Z�CJ` 1�0 GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8308 ttilr iirp:tlurkn.t.t.i Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATE 11/06/14 `�A4.�2oG21 ., K BENDER To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician II 333 W 7th Ave Ste 100 RECEIVED Anchorage, AK 99501 NOV 0 6 2014 DATA TRANSMITTAL AOGCC BCU 24 Elog data Prints: ROP Rate of Penetration, DGR Dual Gamma Ray, EWR-Phase 4, ALD Azimuthal Lithodensity, CTN Compensated Thermal Neutron MD DGR Dual Gamma Ray, EWR-Phase 4, ALD Azimuthal Lithodensity, CTN Compensated Thermal Neutron TVD CD: ; , CGM 9/26/2014 1:44 PM File folder 4, DLIS+L.AS 9/26/2014 1:44 PM File folder J, EMF 9,/26/20141:44 PM File folder 4. PDF 9/26/20141:44 PM File folder „ TIFF 9/26/2014 1:44 PM File folder Please include current contact information if different from above. Please acknowledgep),ALL4.-e, receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received 6...,,aeet Date: 2.k,_ ,‘,. II Seth Nolan Hilcorp Alaska, LLC 2. 045GeoTech 3800 Centerpoint Drive Anchorage, AK 99503 Tele: 907 777-8308 Hilrnrp AlitAR.LI i Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATA LOGGED l\/C01201 4 :.i,K. BENDER DATE 11/06/2014 To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician II 333 W 7th Ave Ste 100 RECEIVE,. Anchorage, AK 99501 NOV 0 6 2014 DATA TRANSMITTAL AOGCC BCU 24 Mudlog data Prints: End of Well Report 2" MD Formation Evaluation Log 5" MD Formation Evaluation Log 2" MD Gas Ratio Log 2" MD Drilling Engineering Log CD: Final Well Data A Files Currently on the Disc (5) j, BEAVER CREEK UNIT 24 FINAL LOGS 10/28/201410:41 ... File folder J, BEAVER CREEK UNIT 24 LAS EXPORTS 10/28/2014 10:41 ... File folder J. EMF Log Viewer 10/28/2014 10:41 ... File folder Halliburtcn Log bie.o,er 10/28/2014 10:41 ... File folder Li BEAVER CREEK UNIT 24 FINAL END OF'N... PDF Document 6,798 KB 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: l (17)�q� V / j...eoteatte: � �©F�f�� 1E S�A'IE ;_ uta �1 , 02_tO-� i h ,.;.,,1, (1u1 / 'i / 1— ` / Q ; ! -_ __:7---:'2-;.: ! _ - . - 333 Wesi Seventh Avenue '= �__�,// G0\'S hNOR ;1 ,\\ P \R\l_ L1. Anchorage, Alaska 99501 3572 '''' iii !v1; it o07 27n A33 Stan Porhola Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Beaver Creek Field, Undefined Tyonek Gas Pool, BCU 24 Sundry Number: 314-581 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, Daniel T. Seamount, Jr. Commissioner DATED this_day of November, 2014. Encl. STATE OF ALASKA �;, Zul ALASKA OIL AND GAS CONSERVATION COMMISSION 4 Dsr 1� APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AOC"ay 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod❑ Repair WeH❑ Change Approved Program 0 Suspend❑ Plug Perforations❑ Perforate 0 . Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Wel ❑ Stimulate❑ Aker Casing❑ Other. Initial Completion 0• 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number Exploratory ❑ Development ❑✓ • 214-112 • 3.Address: 3800 Centerpoint Dnve,Suite 1400 Stratigraphic ❑ Service 1116.API Number. Anchorage,Alaska 99503 50-133-20639-00 7. If perforating: virWell Name and Number. What Regulation or Conservation Order governs well spacing in this pool? be 20AAC25.055(a)j4) 42' �� Beaver Creek(BCU)24 • Will planned perforations require a spacing exception? Yes El No 0r ..':.3L' 9.Property Designation(Lease Number): 10.Field/Pool(s). A028083 Beaver Creek I Undef Tyonek Gas Pool 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): 11,300 10,697 11,191 10,588 WA WA Casing Length Size MD TVD Burst Collapse Structural Conductor 70' 16" 70' 70' Surface 3,187' 9-5/8" 3,187' 2,933 5,750 psi 3,090 psi Intermediate Production 11,284' 5-1/2" 11,284' 10,681' 10,640 psi 7,460 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A N/A WA N/A Packers and SSSV Type: Packers and SSSV MD(t)and TVD(ft): N/A;N/A N/A;N/A 12.Attachments: DescriptionSummary of Proposal E13.Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphicn Development n Service n 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 11/10/14 Oil ❑ 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 Pothole Phone: 907-777-8412 Email sDorholaehilcorD.corn Printed Name Stan Porhola Title Operations Engineer Signature s Phone 907-777-8412 Date 1(9/?V ie't COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. \i"— _ Sg Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: lieM CT— IA � 4 i L C ►-, `j ,,_.: •-e-_- 7 ---rt) Spacing Exception Required? Yes ❑ No [ Subsequent Form Required: f C` —� LiC 7 / ,)is�.� bi,e ( � `'jP�a -) APPROVED BY ) Approved by: / COMMISSIONER THE COMMISSION Date: i / / �/11lL( SubmitFon and gpRell Form 10-403(Revised 10120 ) r a r 1 for 12 mo ha from the date of a prove!. Attachments inn Duplicate Well Prognosis Well: BCU-24 Hilcorp Alaska,La.' Date:10/29/2014 Well Name: BCU-24 API Number: 50-133-20639-00 Current Status: New Grassroots Gas Well Leg: N/A Estimated Start Date: November 10th, 2014 Rig: N/A Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 214-112 First Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228(M) Second Call Engineer: Paul Chan (907)777-8333 (0) (907)444-2881 (M) AFE Number: 1412278C Current Bottom Hole Pressure: — 0 psi @ 10,587' TVD (No open perforations) Maximum Expected BHP: — 5,285 psi @ 10,587' TVD (Based on offset wells, EMW= 9.6ppg) Max.Allowable Surface Pressure: —4,226 psi (Based on actual reservoir conditions and gas gradient to surface (0.10psi/ft) Brief Well Summary Beaver Creek Unit#24 was drilled as a Grass roots monobore completion in 2014 to target gas sands in the Sterling, Lower Beluga, and Tyonek formations. The purpose of this work/sundry is to perforate the well for the initial completion in the Tyonek. Notes Regarding Wellbore Condition • Plan to tag with slickline before running E-line. Moderate dogleg below the KOP @ 1,034' MD. • Will run Cement Bond Log before perforating. • MIRU Coil Tubing and perform BOPE Test to 250/4,500 psi to displace well over to Nitrogen. • Well will be displaced with Nitrogen before initial perforating at+/-3,500 psi SITP. • Pressure test IA(5-1/2"x9-5/8")to 2,500 psi before perforating. y /�ltcl p- c3 pllT—[.4- �c-f --1") E-line Procedure: )4_ (i3.et 1. MIRU E-line, PT lubricator to 4,500 psi Hi 250 Low. a. Tree connection is 9.5" OTIS. b. SITP will be 3,500 psi (Nitrogen pressure). 2. RU 3-1/8" 6 spf Connex HC wireline guns. 3. RIH and perforate the following intervals: Zone Sands Top(MD) Btm (MD) FT SPF Tyonek T20 11,130' 11,190' 60' 6 a. Bleed tubing pressure to 3,500 psi before perforating. b. Proposed perfs shown on the proposed schematic in red font. c. Final Perfs tie-in sheet will be provided in the field for exact perf intervals. d. Correlate using Cement Bond Log(pending Tie-in log). e. Use Gamma/CCL/to correlate. Utilize Press/Temp tool if available. f. Record tubing pressures before and after each perforating run. g. Proposed intervals are in the Undef Tyonek Gas Pool. Well Prognosis Well: BCU-24 IIilcor')Alaska,LLI Date: 10/29/2014 h. Distance to nearest well open in same sands=No wells completed in Tyonek. (No longer planning to perforate the BCU-23(PTD 214-093)in the Tyonek.) i. Spacing allowance is based on 20 AAC 25.055(a)(4); no wells within 3,000 ft. ✓( 4. RD E-line. CQ%z-); /9,o 5. Turn well over to production. J V 'Ii (ems w►� G�c� -� - -c c .�l '4_ cte, E-line Procedure(Contingency): �c��t,� �� 6r' � t . c 6. If any zone produces sand and/or water. / 7. MIRU E-line, PT lubricator to 4,500 psi Hi 250 Low. a. Tree connection is 9.5" OTIS. b. SITP will be+/-3,500 psi (remaining gas or applied Nitrogen pressure). 8. RIH and set 5-1/2" CIBP at depth above zone. Or 9. RIH and set 5-1/2" Casing Patch across the zone. Attachments: 1. Actual Schematic 2. Proposed Schematic • BCU - 24 ACTUAL Pad 3 1,127FNL, 1,645'FWL, SCHEMATIC Sec. 34, T7N, R10W, S.M. 1111corp Alaska,LLE Permit#: 214-112 I » - C16,duct or iX-56 109 ppf API#: 50-133-20639-00 . „ tt I. rla. Top Bottom Prop.Des: FED A-028083 2 .4-. MD 0' 70' KB elevation: 179.2' (18.6'AGL) ' TVD 0' 70' Lat: N60° 39' 30.871" Lona: W151° 1' 2.842" r,i Spud: 9/22/2014 16:00 hrs Surface Casing « TD: 10/09/2014 06:00 hrs ' „ 9-5/S" L-8o 40 ppf BTC Rio Released: 10/16/2014 16:00 hrs s Top Bottom i% `1"; MD 0' 3,187 1 - TVD 0' 2,933' :w *i- 1 12-1/4"hole Lead Cmt w/525 sks(230 bbls)of •Tree cxn=9-1/2"Otis i 12.0 ppg,Class G, Tail Cmt w/230 sks(50 bbls) 8.0"Seal Diameter »t. '' .n of 15.4 ppg,Class G, 180 sks(78 bbls)to surface 5-1/8"Modified ID Bore 61" j , 4. Production Casing TOC(EST)-2,800' t; 5-1/2" P-110 17 ppf CDC I Top Bottom •RA MkrJt 5,799' MD 0' 11,284' TVD 0' 10,681' 8-1/2"hole Cmt w/1,945sks(471 bbls)of 15.3 ppg, Class G cmt w/EASYBLOK IRA MkrJt 7,948' a ay i Casing/Cementinq Detail - 10.4 ppg Mud RA Mkr Jt 8,172' - 11.5 ppg Mud Push(35 bbl) - 15.3 ppg Cement(471 bbl) - 8.5 ppg 3%KCI(255 bbl) 0 .RA MkrJt 8,624' i IiV, RA Mkr Jt 8,934' 1. k.r RA MkrJt 9,825' Jewelry Depth 1.Swell Packer(21'Long) 2,993' RA MkrJt 10,837' ' Perforations: Zone MD TVD Size SPF Date Status •�RA MkrJt 11,102' Tag(unset cement)@ 11,176'SLM _ t 7 Casing Shoe @ 11,284' Max Dogleg: w/4.53"GR NO--'' '# 6.59°/100'@ 1,034' TD: PBTD: 11,300'MD 11,191'MD Max Inclination: 10,697'TVD 10,588'TVD 29.4°@ 2,826' Well Name&Number: Beaver Creek Unit#24 Lease: A-028083 County or Parish: Kenai Peninsula Borough State/Prov: Alaska Country:lUSA Angle @KOP and Depth. 1.5°@ 500' Angle/PerfsI N/A Maximum Deviation: 29.4°@ 2,826' Date Completed: N/A Ground Level(above MSL): 160.6' RKB(above GL): 18.6' Revised By. Stan Porhola Downhole Revision Date: 10/21/2014 Schematic Revision Date: 10/27/2014 BCU - 24 PROPOSED 11:1Pad 3 1,127 FNL, 1,645'FWL, SCHEMATIC Sec. 34, T7N, R10W, S.M. Ilileorp Alaska,LLC Permit#: 214-112 - Conductor ' '1,416" X-56 109 ppf API#: 50-133-20639-00 " -�' Top Bottom Prop.Des: FED A-028083 h **, ,fit*'; • MD 0' 70' KB elevation: 179.2' (18.6'AGL) a ND 0' 70' Lat: N60° 39' 30.871" , ',`' Long: W151° 1' 2.842" �. • , Spud: 9/22/2014 16:00 hrs Surface Casing TD: 10/09/2014 06:00 hrs ,' 9-5/8" L-80 40 ppf BTC Rig Released: 10/16/2014 16:00 hrs Top Bottom ),,,f.,,, y..' MD 0' 3,187' "y s* TVD 0' 2,933' yA 1 12-1/4"hole Lead Cmt w/525 sks(230 bbls)of Tree cxn=9-1/2"Otis ,,e i ,0,4 12.0 ppg,Class G, Tail Cmt w/230 sks(50 bbls) 8.0"Seal Diameter (•. t k of 15.4 ppg,Class G, 180 sks(78 bbls)to surface 5-1/8"Modified ID Bore i:,..1,1 =s" T (EST) , �� Production Casing OC -2800' t"y 5-1/2" P-110 17 ppf CDC I Top Bottom RA MkrJt 5,799' MD 0' 11,284' ND 0' 10,681' 8-1/2"hole Cmt w/1,945sks(471 bbls)of 15.3 ppg, Class G cmt w/EASYBLOK ! ".RA Mkr Jt 7,948' '' rCasing/Cementing Detail - 10.4 ppg Mud RA Mkr Jt 8,172' - 11.5 ppg Mud Push(35 bbl) - 15.3 ppg Cement(471 bbl) f- - 8.5 ppg 3%KCI(255 bbl) ;iir R• A MkrJt 8,624' r IA if, -4- ir R• A Mkr Jt 8,934' Fly ,' �A RA Mkr Jt 9,825' s 4U.y Jewelry Depth " 1.Swell Packer(21'Long) 2,993' i 11."' 11.150' R• A MkrJt 10,837' 10 Perforations: dt'. Y,.111 ,t° Zone MD TVD Size SPF Date Status ddd���� ": Tyonek 11,1'2. 190' 587' • RA MkrJt 11,102' Tyonek — ; Tag(unset cement)@ 11,176'SLMt 0 Casing Shoe @ 11,284' Max Dogleg: w/4.53"GR(10/21/14) "+ - 6.59°/100'@ 1,034' TD: PBTD: Max Inclination: 11,300'MD 11,191'MD 10,697'ND 10,588'ND 29'4°@ 2'826 Well Name&Number: Beaver Creek Unit#24 Lease: A-028083 County or Parish Kenai Peninsula Borough Stale/Prov: Alaska Country USA Angle @KOP and Depth 1.5°@ 500' Angle/Perfs:I N/A Maximum Deviation 29.4°@ 2,826' Date Completed: N/A Ground Level(above MSL): 160.6' RKB(above GL): 18.6' Revised By Stan Porhola Downhole Revision Date Proposed Schematic Revision Date: 10/29/2014 Schwartz, Guy L (DOA) From: Schwartz,Guy L(DOA) Sent: Monday, November 03, 2014 12:17 PM To: 'Stan Porhola' Subject: RE: BCU 24 (PTD 214-112) Stan, I will make the sundries contingent on a passing MIT-IA then. Forward the CBL as soon as practical. 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@hilcoro.com] Sent: Monday, November 03, 2014 11:45 AM To: Schwartz, Guy L(DOA) Subject: RE: BCU 23 (PTD 214-093) Guy, We have run the cement bond logs in both BCU-23 (PTD 214-093) and BCU-24(PTD 214-112). I should have the hard copy and electronic copies in my office today. Will put together copies to submit to your office. Plan to perform the MIT-IA for both wells this later this week or next. Stan From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Monday, November 03, 2014 10:16 AM To: Stan Porhola Subject: BCU 23 (PTD 214-093) Stan, Has the CBL been run on BCU 23? Also MIT-IA results? Need to have these results before I approve perforating sundry. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 1 • 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). 2 II Seth Nolan Hilcorp Alaska, LLC 2--(z4Z GeoTech 3800 Centerpoint Drive 5f>8 Anchorage, AK 99503 Tele: 907 777-8308 1{ilciirp 11114a.1.11 Fax: 907 777-8510 E-mail: snolan@hilcorp.com DATE 11/03/2014 To: Alaska Oil & Gas Conservation Commission Meredith Guhl litatingdurterhnician.---_- 333 W-7tTi Ave Ste 100 Anchorage, AK 99501 DATA TRANSMITTAL 10 boxes: Dry Cuttings Transmitted herewith are cuttings from BCU 24 WELL SAMPLE INTERVAL BCU 24 3200'—3880' BCU 24 3880'—4800' BCU 24 4800'—5760' BCU 24 5760'—6680' BCU 24 6680'—7540' BCU 24 7540'—8280' BCU 24 8280'—9020' BCU 24 9020'—9860' BCU 24 9860'—10840' BCU 24 10840'—11300' 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 Receive ..,LS1Date: RECEIVED NOV 3 2014 AOGCC Itta( z4 I3riZA,4tz Regg, James B (DOA) From: Jimmy Greco - (C) <jgreco@hilcorp.com> Sent: Wednesday, October 15, 2014 9:39 AM To: Regg, James B (DOA) Subject: RE: Notification of use of BOP equipment These were tested @ 10:00 am on 10-13-2014 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Wednesday, October 15, 2014 9:10 AM To: Jimmy Greco - (C) Subject: RE: Notification of use of BOP equipment Thanks.Just one more questions—when were these tested? Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: Jimmy Greco - (C) [mailto:jgreco@hilcorp.com] Sent: Tuesday, October 14, 2014 6:56 PM To: Regg, James B (DOA) Subject: RE: Notification of use of BOP equipment Choke valves 1,2,3,7,& 12 were testes with rams @ 250 to/4000 psi, annular was tested @ 250/2500 psi. From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, October 14, 2014 3:47 PM To: Jimmy Greco - (C); DOA AOGCC Prudhoe Bay Cc: Monty Myers; Rance Pederson - (C) Subject: RE: Notification of use of BOP equipment Did you also test the choke? Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 1 CONFIDENTIALITYNOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Corimission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or iim.regg@alaska.gov. From: Jimmy Greco - (C) [mailto:jgreco@hilcorp.com] Sent: Sunday, October 12, 2014 1:57 AM To: DOA AOGCC Prudhoe Bay; Regg, James B (DOA) Cc: Monty Myers; Rance Pederson - (C) Subject: Notification of use of BOP equipment 2 Notification for use of Blowout Equipment Date: 10-12-2014 Shut In Time: 01:22 Location: BCU -24 PTD#: 214-112 Rig: Saxon 169 Drilling Foremen: Rance Pederson &Jimmy Greco, Hilcorp Alaska BOP used: 11" 5M, Annular Preventer Reason: Mud loggers gas detecting monitors, Total safety gas monitors showing 21%gas @ shakers. Casing Window depth: 3187 Summary: We were tripping in to a depth of 11,300, while tripping in @10132' we were reaming out a bridge we started getting gas cut mud over shakers, mud weight was cut by gas .9 tenth pound Fl 10.1 T/9.2, Shut well in circulate gas out through choke. Last BOP test date: 10-11-2014 The Annular Preventer will be re-tested on the next trip out of the hole, prior to re-entry. Current Depth: 10132' @ 01:22 Jimmy Greco, Drilling Foreman Hilcorp Alaska Jgreco @hilcorp.com, 907-776-6776 rpederson @ Hilcorp.com, 907—776-6776 �w�\ i%%i ,.s., 'I - HE STATE , g G'T // !.ii'--1--r"1-`---;_:-:::_f,-_::, ,. 1 e!. _ ) r .�_4111,W=:=;.4-: -------------- 333 Wesi Sc ei t!; Av r ue IL-iv.P74t,. (iOVI- NOR _1:.1�! P:\R`'E_I1Ancnora�c, Alaska99501 35%2 . r4nii i 9c7 279 ' nom: Monty Mack Myers Drilling Engineer Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: Beaver Creek Field, Beluga Gas Pool, Beaver Creek#24 Hilcorp Alaska, LLC Permit No: 214-112 (revised) Surface Location: 1127' FNL, 1645' FWL, Sec. 34, T7N, RIOW, SM, AK Bottomhole Location: 2361' FSL, 1539' FEL, Sec. 34, T7N, R1 OW, SM, AK Dear Mr. Myers: Enclosed is the approved application for permit to drill the above referenced development well. This permit supersedes and replaces the permits previously issued for this well dated July 30, 2014 and September 10, 2014. 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, P-73-Lf. Cathy P. oerster Chair DATED this 3 day of October, 2014. STATE OF ALASKA RECEIVED������ A, A OIL AND GAS CONSER TIOIVCOMM. Al PERMIT TO DRIL `- REVISION 2 SEP 3 o ?1i14 20 AAC 2 005 __- la.Type of Work: lb.Proposed Well Class: Development-Oil El Service- -- —- Single Zone Q • lc.Specify if well is proposed for: Drill ❑✓ • Lateral ❑ Stratigraphic Test ❑ Development-Gas❑Q • Service-Supply ❑ Multiple Zone ❑ Coalbed Gas❑ Gas Hydrates ❑ Redril❑ Reentry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Q Single Well ❑ 11.Well Name and Number: Hilcorp Alaska,LLC Bond No. 022035244 • Beaver Creek#24 . 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive,Suite 1400,Anchorage AK 99503 MD: 11,400' • TVD: 10,796' ` Beaver Creek Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Beluga Gas • Surface: 1127'FNL, 1645'FWL,Sec 34,T7N,R1OW,SM,AK . A028083 • Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 2102'FNL,2559'FEL,Sec 34,T7N,R1OW,SM,AK NA 9/21/2014 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 2361'FSL,1539'FEL,Sec 34,T7N,R1 OW,SM,AK 1920 acres(A028083) i 2569'FEL,2131 FNL 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 179.2 feet 15.Distance to Nearest Well Open Surface: x-317464.359 • y-2434055.893 . Zone-4 GL Elevation above MSL: 160.6 feet to Same Pool: 1,200' 16.Deviated wells: Kickoff depth: 2,000 feet • 17. Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 27 degrees • Downhole: 3800 psi .- Surface: 2720 psi 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Cond 16" 109 X-56 Weld 80' Surf. Surf. 80' 80' Driven 12-1/14" 9-5/8" 40 L-80 BTC 3,200' Surf. Surf. 3,200'. 2,945' ,,30 3bb1/1713.9ft3 8-1/2" 5-1/2" 17 P-110 DWC/C HT 11,400' Surf. Surf. 11,400' 10,796' ( 365 bbl/2050.4ft3 `I 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): ',Perforation Depth TVD(ft): 20. Attachments: Property Plat Q BOP Sketch Q Drilling Program Q Time v.Depth Plot Q Shallow Hazard Analysis Diverter Sketch Q Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Monty Mack Myers Email mmyers(C7hilcorp.com Printed Name Monty Mack Myers Title Drilling Engineer Signature '"% Phone (907)777-8431 Date 9/29/2014 Commission Use Only Permit to Drill ., / API Number: Permit Approval /4/ See cover letter for other Number: f_ //� 50-,��AO� cc;Date: ��3� 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 Other: &cif ' Samples req'd: Yes❑ No13/ Mud log req'd:Yes❑ No[P'• H2S measures: Yes❑ No[v]a Directional svy req'd:Yes i� No❑ / ^L ,r^ 'r- 1,' re? `cei( Spacing exception req'd: Yes❑ Not?' Inclination-only svy req'd:Yes❑ No . - v......„..____ fApproved by: 9ç?(47 AtOTMMISSION Date: /0 -3 -77 iO f•/f OJRTE1 Submit Form and/ Form 10-401(R- ised 10/2012)/This permit is valid for 24 months from the date of approval(20 AAC 25.005tip Attachments• Duplicate (PO4'. -, /. �y Monty Myers Hilcorp Alaska, LLC Drilling Engineer P.O. Box 244027 Anchorage,AK 99524-4027 Tel 907 777 8431 Email mmyers@hilcorp.com Hileorp Alaska,LLC September 29, 2014 Commissioner Alaska Oil&Gas Conservation Commission 333 W. 7th Avenue ` .D Anchorage,Alaska 99501 Re: Beaver Creek (BCU)#24—Revised PTD#2 i ta0 Dear Commissioner, This is a revision to the previously submitted and approved PTD for Beaver Creek#24. The major change to this PTD is the proposed depth of the well being changed from 9,675'TMD(9,080'TVD)to a new proposed depth of 11,400' TMD(10,796'TVD).This change is necessary to evaluate some lower sands that were seen in the recently drilled Beaver Creek#23. ti:r-. .-/A. C'et ezr c -✓ c� �-r 5 S 41D A' (6 - Drilling operations are currently underway. /2. The Saxon Rig#169 will be used to drill the wellbore then run casing and cement. All waste&mud generated during drilling and completion operations will be hauled to the Kenai Gas Field G&I / facility for disposal/beneficial reuse depending on test results. General sequence of operations: 1. MOB Saxon Rig#169 to well site 2. N/U 21-1/4"x 2M diverter. 3. Drill 12-1/4" hole to 3500' MD. Run and cmt 9-5/8"surface casing. 4. N/D diverter, N/U&test 11"x 5M T3-Energy BOP. 5. Drill 8-1/2" hole section to.1A,8O MD. Perform Wiper trip. 6. POOH laying down drill pipe. I1,41A2' 7. Run and cmt 5-1/2" production casing. 8. N/D BOP, N/U temp abandonment cap, RDMO. Hilcorp Alaska, LLC Page 1 of 2 Monty Myers Hilcorp Alaska, LLC Drilling Engineer P.O. Box 244027 Anchorage, AK 99524-4027 Tel 907 777 8431 Email mmyers@hilcorp.com Hilrorp Alaika, Reservoir Evaluation Plan: 1. Surface hole:GR+Res LWD. 2. Production Hole:GR+Res+Den/Neu LWD. 3. Mud loggers from surface casing point to TD. 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 2 of 2 Hilcorp Energy Company Beaver Creek Unit Beaver Creek Unit Beaver CK Unit 24 BCU 24 Plan: BCU 24 WP6.0 Standard Proposal Report 29 September, 2014 immomism 'i HALLIBURTON Sperry Drilling Services HALLI BU RTON Project' Beaver Creek Unit Site: Beaver Creek Unit Sperry Drilling Well: BeaverBCU24 CK Unit 24 Wellbore: SECTION DETAILS BCU 24 WP6.0 c MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target 3200.00 27.62 137.33 2945.12 -776.03 752.56 0.00 0.00 1080.26 CASING DETAILS 2 3284.72 27.62 137.33 3020.18 -804.91 779.18 0.00 0.00 1119.46 BCU 24 Shallow Tgt wp3 3 3366.29 27.42 132.05 3092.54 -831.40 805.94 3.00 -97.14 1157.11 TVD MD Name Size 4 5800.29 27.42 132.05 5253.18 -1582.02 1638.13 0.00 0.00 2277.31 BCU 24 BC_B4ST Tgt wp3 2945.12 3200.00 9 5/8" 9-5/8 5 6921.02 5.00 131.81 6322.52 -1790.06 1869.07 2.00 -179.95 2588.00 3 8169.72 5.00 131.81 7566.47 -1862.63 1950.20 0.00 0.00 2696.78 10796.43 11400.00 51/2" 5-1/2 7 8419.75 0.00 131.96 7816.18 -1869.90 1958.32 2.00 180.00 2707.68 BCU 24 Mid Tgt wp3 3 11400.00 0.00 131.96 10796.43 -1869.90 1958.32 0.00 131.96 2707.68 • SURVEY PROGRAM 0- Date:2014-09-29T00:00:00 Validated:Yes Version: - Depth From Depth To Survey/Plan Tool 249.00 786.89 BCU 24 Rig Surveys(MWD+SC+sag)(BCU 24) MWD+SC+sag 750- 848.00 971.00 BCU 24 Rig Surveys(MWD InterpAzi+sag)(BCU 24) MWD_Interp Azi+sag 1034.00 3200.00 BCU 24 Surveys(MWD+SC+sag)(BCU 24) MWD+SC+sag - 3200.00 11400.00 BCU 24 WP6.0(BCU 24) MWD+SC+sag 1500- WELL DETAILS: Beaver CK Unit 24 _ Ground Level: 160.18 +N/-5 +E/-W Northing Easting Latittude Longitude Slot 0.00 0.00 2434055.89 317464.36 60.6585752 -151.0174560 2250- - 9 5/8 BCU 24 Rig Surveys -- 3000 - - - - - - - - - - - ' BCU 24 Shallow Tgt wp3 SHALLOW GASStart Dir 3°/100':3284.72'MD,3020.18'TVD 3750- c - - - End Dir :3366.29'MD,3092.54'TVD m = 4500- o _ 0 1.0 - B2 Start Dir 2°/100':5860.29'MD,5253.18'TVD C5250 - - - - - = __ - BCU 24 BC_B4ST Tgt wp3 0B4 m 6000- _ _ _ _ _ _ _ __ _ Hilcorp Energy Company 2 - UBC3 End Dir :6921.02'MD,6322.52'TVD Calculation Method: Minimum Curvature I- - Error System:ISCWSA 6750- Scan Method: Closest Approach 3D - Error Surface: Elliptical Conic - B18 Warning Method: Error Ratio - - - - - - - - - - - - - - - - - - Start Dir 2°/100':8169.72'MD,7566.47'TVD 7500- --B24 --B28B- _ - - - - - - End Dir :8419.75'MD,7816.18'TVD 8250-', -- - - - - - - - - -- - B3O •. REFERENCE INFORMATION - - - - - - - - - - - - -- - - - - - BCU 24 Mid Tgt wp3 Co-ordinate(N/E)Reference: Well Beaver CK Unit 24,True North Vertical(ND)Reference: Actual:BCU 24 @ 178.18usft((160.18 GL+18 KE 9000- Tyonek Measured Depth Reference: Actual:BCU 24 @ 178.18usft((160.18 GL+18 KE Calculation Method: Minimum Curvature FORMATION TOP DETAILS 9750- TVDPath MDPath Formation 3016.10 3280.11 SHALLOW GAS 5058.10 5580.53 B2 5249.10 5795.70 B4 10500- 6068.10 6664.28 UBC3 5 1/2" 7264.10 7866.20 B18 I 7777.10 8380.67 B24 d _ 7920.10 8523.67 B28B BCU 24 WP6.0 8198.10 8801.67 B30 11250- 8700.10 9303.67 Tyonek Total Depth: 11400'MD,10796.43'ND -1500 -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 Vertical Section at 133.76° (1500 usft/in) EE I C' YY 11 G) w �' CO CO00 N• / 7 H Q ---r1 Np iAo)1n op N C1) Y cc o c UUUVQ Z�r MtON `° L. d d m et 2» z W 10 0 N —o rCI 03 03 C4 F11 + Q > > et N o mmm ` c.-.-m F macnm o '^ Qoi - o 44 0 CO- z 7@ME W 0200 ,VN). \0 � V —"a 0 Y•t l io ❑ U C CO CO H N Q1 '1Lo 3 .E2 k Q U'=Z + I+ + 00 N 00 O _ N U UU U' ❑O 0 ❑❑❑❑ M O ), v CC �mm= X00 I-°-2222 ') co - - o 0_ mm0E Z c1U oN -. ->>. � 4.1 — O CI oN W <2 N i. ' 1 co _- z O O Cal W I Q _ ui N V N N N Cr,N \ y I j —h 7 .0 I O - N o N mow.. >O060 1)O N Nm 00 1 1 _ Caw$N "O mNN CD A, O \ 'G \ 1 1 _ fV C�'T.d.= 0 W T .. {l . }. \\ \\ 11 1 h -—0 ..q.'42(7", OU — LL' > U d N O \ \• I ' - N a U>1 r p 000 - a— + 1+ , , \ , , i , cp - cLu 6 C > co T cr. O O .I� _ _ @ 6) (00,-6 00 \\ ti O 0 N 2 Z U).� d' - y = O.CO W 3 7 o O N \\ I 11 —o U q O 0 C(n(n .0.;) O \ 11 QA _ E' arnN Ow p `a ElY\n mp cl- M 0 \ I 1 _ 00 O E�w n o c'' 5:sr sr d.1 \ I 1 _ ✓ C U o_t .N N N N 1 I - o Lc.oUill W I! DDDD jUUUU N •4 l Cw." 11 M '0 o E ❑ J PEW (nmmmm 0 _ C 7 Zr,N 0 Q 2\n2co2 N \ \ VD - o W ' M \ 0., ycyO H —1c c,W M .4iO �� CO M O riWNLE 2 U 4 N m,- o C) . N - 0 0 p M \n O 'n T A f L>0.1 U _ .. 7 O I U N 0 t 1oo F. v NN —000 Gel C a 1n V] 1 7 Y co-8'g am 0 00 00 oo \ I 1 al I - fJ] 0 Om,� 11 0110 fr \\ , U - 1 1 co 0 JO tN10N ` \ I I _ t- o Co 0MI 0 O N M D 1 • \\ I 1 N —o co 03 > - O co J J 1/A1 U I- F .O C ,'r,i17J C• m 1- ❑ OLLIC I \\ - s t U a J O n I (n m W M \ - N N N N I `\ M —0 61 O) Cat 1 I \ _ z 1 O \ EW G V 11FF 06]001 M U , - 0- yN1.-M 0t,t01 1 3 >O 0.;1,t`11 NN N O O M 1y-,1)N1 W 00 ,n - O,�N10,ONN C� •— N N N N N �O G1 ' - O - _000100001 W Oi 0 1I. 000."00000 0000^00 + N _ 0 _1 I-0 . .00000000 000000000 J ❑OOMONONO O NNecc n Zo+CUq _—O 03FMFONMM - I N W O M W O 1 1 - O z +NNm101WWWW —w O F W .0mv00comm Z Z 101"N0NWW - O ir1110�111 M A 0111 N1.-0M — P 6 O N 6 N 10,O,6 iM 0 1N W,0N1F W —N WOONMLOCN N MM101 N NO 7yMMOO110:0? O 3 01 O N N N N 0 0 0 0 M = 066v-4-0000 W NNNNt01lOO 0 u 'L _0, JO 00N0WNN100 - �ONOI-NN 0,NN,0 JOFvIOOONIWO'O - 0 �, MCN')rMi,1n 10111 IIIIIj IIII IIII IIII IIIIII II It IIj IIIIII IIIj IIII II III III IIII 2 Q W 0 0 0 0 0 0 0 0 0 0 0 0 0 1 M N T 00 N C NV 0 01 I Q 2—.c,-,1,011--1 ~ in (u?/13511 Oct)(+)47�oN/(-)41nos .. - - O c _ s; aigNp - c)000a -o > ; N tl• - M 10 to 10 N - °1 c, 03 ci I•V - N w O MW - V y+ d 4 .. _ N 0 7/ 0 V 1—r, a - N 3 N = M p N U —O ° w - N MVO o U 1 - .7 F" o. 1 I 1 - o UM (/] N W 'Cf' 1 1 1 - N 0a 1 1 1 - 1 1 1 1 U ‘ 1 I - 1 r= oo N N 11 11 1 / - N CO ` cNi 1 16 - U 44 0 Ia w) N O - • 0 U 1 —o b M - • O d J a .`� VA — co - 1 3o 0 o � _ = UC V1 N - o c `- u N - CI 0 M N 1 1 1 ..'' , 1 I I , — cal 1 1 1 an I _ 1 1 1 _ �,� —o o0 ell! I ISN 1 M - I - �] I I, .__co G .`7 _ �1 I , u `? U _ _ a P . `� L; 1 r 1 - I� ti 1- ria 1; 2\''' I/ .. te .�� U -- - 0 •• •• - 0 • s. _ N I M - omit 0 U - ml LiiiliIiiiiiiiiiiiliiiiiiiillliiiii , i IIIIIIIIIImI1111I1mI11i1iiiiiim iii 111 Q L o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 00 N b b N 00 O b N CO d' O b N e1 M �O W t; N ? b I"- .._, G. I U) (uojsn OOb)(+)g1-IoN/(-)tonos — — — Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 24 Company: Hilcorp Energy Company TVD Reference: Actual:BCU 24 @ 178.18usft((160.18 GL+18 K . Project: Beaver Creek Unit MD Reference: Actual:BCU 24 @ 178.18usft((160.18 GL+18 K Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 24 Survey Calculation Method: Minimum Curvature Wellbore: BCU 24 Design: BCU 24 WP6.0 Project Beaver Creek Unit Map System: US State Plane 1927(Exact solution) . System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Site Beaver Creek Unit Site Position: Northing: 2,430,086.36 usft Latitude: 60.6475877 From: Map Easting: 314,428.19usft Longitude: -151.0340284 Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -0.90 ° Well Beaver CK Unit 24 Well Position +N/-S 0.00 usft Northing: 2,434,055.89 usf . Latitude: 60.6585752 +E/-W 0.00 usft Easting: 317,464.36 usf - Longitude: -151.0174560 Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usf Ground Level: - 160.18 usft Wellbore BCU 24 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1 (°) (nT) BGGM2014 6/12/2014 17.02 73.63 55,453 Design BCU 24 WP6.0 Audit Notes: Version: Phase: PLAN Tie On Depth: 3,200.00 Vertical Section: Depth From(TVD) +NI-S +E/-W Direction (usft) (usft) (usft) (0) 18.92 0.00 0.00 133.76 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +EI-W Rate Rate Rate Tool Face (usft) (°) (0) (usft) usft (usft) (usft) (°/100usft) (°/100usft) (°/100usft) (0) 3,200.00 27.62 137.33 2,945.12 2,766.94 -776.03 752.56 0.00 0.00 0.00 0.00 3,284.72 27.62 137.33 3,020.18 2,842.00 -804.91 779.18 0.00 0.00 0.00 0.00 3,366.29 27.42 132.05 3,092.54 2,914.36 -831.40 805.94 3.00 -0.25 -6.47 -97.14 5,800.29 27.42 132.05 5,253.18 5,075.00 -1,582.02 1,638.13 0.00 0.00 0.00 0.00 6,921.02 5.00 131.81 6,322.52 6,144.34 -1,790.06 1,869.07 2.00 -2.00 -0.02 -179.95 8,169.72 5.00 131.81 7,566.47 7,388.29 -1,862.63 1,950.20 0.00 0.00 0.00 0.00 8,419.75 0.00 131.96 7,816.18 7,638.00 -1,869.90 1,958.32 2.00 -2.00 0.00 180.00 11,400.00 0.00 131.96 10,796.43 10,618.25 -1,869.90 1,958.32 0.00 0.00 0.00 131.96 9/29/2014 1:57:42PM Page 2 COMPASS 5000.1 Build 70 Halliburton HALLIBURT0N Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 24 Company: Hilcorp Energy Company TVD Reference: Actual:BCU 24 @ 178.18usft((160.18 GL+18 k Project: Beaver Creek Unit MD Reference: Actual:BCU 24 @ 178.18usft((160.18 GL+18 k Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 24 Survey Calculation Method: Minimum Curvature Wellbore: BCU 24 Design: BCU 24 WP6.0 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (0) (0) (usft) usft (usft) (usft) (usft) (usft) 2,766.94 3,200.00 ✓ 27.62 137.33 2,945.12 2,766.94 -776.03 752.56 2,433,268.30 318,204.81 0.00 1,080.26 9 5/8" 3,280.11 27.62 137.33 3,016.10 2,837.92 -803.34 777.73 2,433,240.61 318,229.56 0.00 1,117.33 SHALLOW GAS 3,284.72 27.62 137.33 3,020.18 2,842.00 -804.91 779.18 2,433,239.01 318,230.99 0.00 1,119.47 Start Dir 3°/100':3284.72'MD,3020.18'TVD 3,300.00 27.57 136.35 3,033.72 2,855.54 -810.07 784.02 2,433,233.78 318,235.75 3.00 1,126.53 3,366.29 27.42 132.05 3,092.53 2,914.35 -831.40 805.94 2,433,212.12 318,257.34 3.00 1,157.11 End Dir :3366.29'MD,3092.54'ND 3,400.00 27.42 132.05 3,122.46 2,944.28 -841.79 817.47 2,433,201.55 318,268.70 0.00 1,172.63 3,500.00 27.42 132.05 3,211.23 3,033.05 -872.63 851.66 2,433,170.18 318,302.41 0.00 1,218.65 3,600.00 27.42 132.05 3,300.00 3,121.82 -903.47 885.85 2,433,138.82 318,336.12 0.00 1,264.67 3,700.00 27.42 132.05 3,388.77 3,210.59 -934.31 920.04 2,433,107.45 318,369.82 0.00 1,310.70 3,800.00 27.42 132.05 3,477.53 3,299.35 -965.15 954.23 2,433,076.09 318,403.53 0.00 1,356.72 3,900.00 27.42 132.05 3,566.30 3,388.12 -995.99 988.42 2,433,044.72 318,437.24 0.00 1,402.74 4,000.00 27.42 132.05 3,655.07 3,476.89 -1,026.83 1,022.61 2,433,013.36 318,470.95 0.00 1,448.77 4,100.00 27.42 132.05 3,743.84 3,565.66 -1,057.67 1,056.80 2,432,981.99 318,504.66 0.00 1,494.79 4,200.00 27.42 132.05 3,832.61 3,654.43 -1,088.50 1,090.99 2,432,950.63 318,538.37 0.00 1,540.81 4,300.00 27.42 132.05 3,921.38 3,743.20 -1,119.34 1,125.18 2,432,919.26 318,572.08 0.00 1,586.83 4,400.00 27.42 132.05 4,010.15 3,831.97 -1,150.18 1,159.37 2,432,887.90 318,605.78 0.00 1,632.86 4,500.00 27.42 132.05 4,098.92 3,920.74 -1,181.02 1,193.56 2,432,856.53 318,639.49 0.00 1,678.88 4,600.00 27.42 132.05 4,187.69 4,009.51 -1,211.86 1,227.75 2,432,825.17 318,673.20 0.00 1,724.90 4,700.00 27.42 132.05 4,276.46 4,098.28 -1,242.70 1,261.94 2,432,793.80 318,706.91 0.00 1,770.93 4,800.00 27.42 132.05 4,365.23 4,187.05 -1,273.54 1,296.13 2,432,762.44 318,740.62 0.00 1,816.95 4,900.00 27.42 132.05 4,454.00 4,275.82 -1,304.38 1,330.32 2,432,731.07 318,774.33 0.00 1,862.97 5,000.00 27.42 132.05 4,542.77 4,364.59 -1,335.22 1,364.51 2,432,699.71 318,808.03 0.00 1,909.00 5,100.00 27.42 132.05 4,631.54 4,453.36 -1,366.06 1,398.70 2,432,668.34 318,841.74 0.00 1,955.02 5,200.00 27.42 132.05 4,720.31 4,542.13 -1,396.90 1,432.89 2,432,636.98 318,875.45 0.00 2,001.04 5,300.00 27.42 132.05 4,809.07 4,630.89 -1,427.74 1,467.08 2,432,605.62 318,909.16 0.00 2,047.06 5,400.00 27.42 132.05 4,897.84 4,719.66 -1,458.57 1,501.27 2,432,574.25 318,942.87 0.00 2,093.09 5,500.00 27.42 132.05 4,986.61 4,808.43 -1,489.41 1,535.46 2,432,542.89 318,976.58 0.00 2,139.11 5,580.53 27.42 132.05 5,058.10 4,879.92 -1,514.25 1,562.99 2,432,517.63 319,003.72 0.00 2,176.17 B2 5,600.00 27.42 132.05 5,075.38 4,897.20 -1,520.25 1,569.65 2,432,511.52 319,010.28 0.00 2,185.13 5,700.00 27.42 132.05 5,164.15 4,985.97 -1,551.09 1,603.84 2,432,480.16 319,043.99 0.00 2,231.16 5,795.70 27.42 132.05 5,249.10 5,070.92 -1,580.60 1,636.56 2,432,450.14 319,076.25 0.00 2,275.20 B4 5,800.00 27.42 132.05 5,252.92 5,074.74 -1,581.93 1,638.03 2,432,448.79 319,077.70 0.00 2,277.18 5,800.29 27.42 132.05 5,253.18 5,075.00 -1,582.02 1,638.13 2,432,448.70 319,077.80 0.00 2,277.31 Start Dir 2°/100':5800.29'MD,5253.18'TVD 5,900.00 25.42 132.05 5,342.47 5,164.29 -1,611.73 1,671.07 2,432,418.48 319,110.28 2.00 2,321.65 6,000.00 23.42 132.04 5,433.52 5,255.34 -1,639.42 1,701.77 2,432,390.32 319,140.55 2.00 2,362.98 6,100.00 21.42 132.03 5,525.96 5,347.78 -1,664.96 1,730.10 2,432,364.35 319,168.47 2.00 2,401.10 6,200.00 19.42 132.03 5,619.67 5,441.49 -1,688.32 1,756.01 2,432,340.59 319,194.02 2.00 2,435.97 6,300.00 17.42 132.02 5,714.54 5,536.36 -1,709.47 1,779.48 2,432,319.08 319,217.17 2.00 2,467.56 9/29/2014 1:57:42PM Page 3 COMPASS 5000.1 Build 70 Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 24 Company: Hilcorp Energy Company TVD Reference: Actual:BCU 24 @ 178.18usft((160.18 GL+18 k Project: Beaver Creek Unit MD Reference: Actual:BCU 24 @ 178.18usft((160.18 GL+18 k Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 24 Survey Calculation Method: Minimum Curvature Wellbore: BCU 24 Design: BCU 24 WP6.0 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (0) (0) (usft) usft (usft) (usft) (usft) (usft) 5,632.27 6,400.00 15.42 132.01 5,810.45 5,632.27 -1,728.39 1,800.49 2,432,299.84 319,237.87 2.00 2,495.81 6,500.00 13.42 131.99 5,907.30 5,729.12 -1,745.05 1,818.99 2,432,282.89 319,256.12 2.00 2,520.70 6,600.00 11.42 131.98 6,004.95 5,826.77 -1,759.44 1,834.98 2,432,268.25 319,271.88 2.00 2,542.20 6,664.28 10.14 131.96 6,068.10 5,889.92 -1,767.48 1,843.92 2,432,260.08 319,280.70 2.00 2,554.22 UBC3 6,700.00 9.42 131.95 6,103.30 5,925.12 -1,771.54 1,848.43 2,432,255.95 319,285.14 2.00 2,560.28 1 6,800.00 7.42 131.91 6,202.22 6,024.04 -1,781.32 1,859.32 2,432,246.00 319,295.89 2.00 2,574.92 6,900.00 5.42 131.84 6,301.58 6,123.40 -1,788.79 1,867.65 2,432,238.41 319,304.10 2.00 2,586.09 6,921.02 5.00 131.81 6,322.52 6,144.34 -1,790.06 1,869.07 2,432,237.11 319,305.50 2.00 2,588.00 End Dir :6921.02'MD,6322.52'TVD 7,000.00 5.00 131.81 6,401.20 6,223.02 -1,794.65 1,874.20 2,432,232.44 319,310.56 0.00 2,594.88 7,100.00 5.00 131.81 6,500.81 6,322.63 -1,800.46 1,880.70 2,432,226.53 319,316.96 0.00 2,603.59 7,200.00 5.00 131.81 6,600.43 6,422.25 -1,806.27 1,887.20 2,432,220.62 319,323.37 0.00 2,612.30 7,300.00 5.00 131.81 6,700.05 6,521.87 -1,812.08 1,893.69 2,432,214.71 319,329.77 0.00 2,621.02 7,400.00 5.00 131.81 6,799.67 6,621.49 -1,817.90 1,900.19 2,432,208.80 319,336.18 0.00 2,629.73 7,500.00 5.00 131.81 6,899.29 6,721.11 -1,823.71 1,906.69 2,432,202.89 319,342.59 0.00 2,638.44 7,600.00 5.00 131.81 6,998.91 6,820.73 -1,829.52 1,913.18 2,432,196.97 319,348.99 0.00 2,647.15 7,700.00 5.00 131.81 7,098.53 6,920.35 -1,835.33 1,919.68 2,432,191.06 319,355.40 0.00 2,655.86 7,800.00 5.00 131.81 7,198.15 7,019.97 -1,841.14 1,926.18 2,432,185.15 319,361.80 0.00 2,664.57 7,866.20 5.00 131.81 7,264.10 7,085.92 -1,844.99 1,930.48 2,432,181.24 319,366.04 0.00 2,670.34 B18 7,900.00 5.00 131.81 7,297.77 7,119.59 -1,846.95 1,932.67 2,432,179.24 319,368.21 0.00 2,673.29 8,000.00 5.00 131.81 7,397.39 7,219.21 -1,852.77 1,939.17 2,432,173.33 319,374.61 0.00 2,682.00 8,100.00 5.00 131.81 7,497.01 7,318.83 -1,858.58 1,945.67 2,432,167.42 319,381.02 0.00 2,690.71 8,169.72 5.00 131.81 7,566.46 7,388.28 -1,862.63 1,950.19 2,432,163.30 319,385.49 0.00 2,696.78 Start Dir 2°/100':8169.72'MD,7566.47'TVD 8,200.00 4.40 131.81 7,596.64 7,418.46 -1,864.28 1,952.04 2,432,161.61 319,387.31 2.00 2,699.26 8,300.00 2.40 131.81 7,696.46 7,518.28 -1,868.23 1,956.46 2,432,157.60 319,391.66 2.00 2,705.18 8,380.67 0.78 131.81 7,777.10 7,598.92 -1,869.72 1,958.12 2,432,156.08 319,393.30 2.00 2,707.41 B24 8,400.00 0.40 131.81 7,796.43 7,618.25 -1,869.85 1,958.27 2,432,155.95 319,393.45 2.00 2,707.61 8,419.75 0.00 131.81 7,816.18 7,638.00 -1,869.90 1,958.32 2,432,155.90 319,393.50 2.00 2,707.68 End Dir :8419.75'MD,7816.18'ND 8,500.00 0.00 131.96 7,896.43 7,718.25 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 8,523.67 0.00 131.96 7,920.10 7,741.92 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 B28B 8,600.00 0.00 131.96 7,996.43 7,818.25 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 8,700.00 0.00 131.96 8,096.43 7,918.25 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 8,800.00 0.00 131.96 8,196.43 8,018.25 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 8,801.67 0.00 131.96 8,198.10 8,019.92 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 B30 8,900.00 0.00 131.96 8,296.43 8,118.25 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 9,000.00 0.00 131.96 8,396.43 8,218.25 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 9,100.00 0.00 131.96 8,496.43 8,318.25 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 9,200.00 0.00 131.96 8,596.43 8,418.25 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 9/29/2014 1:57:42PM Page 4 COMPASS 5000.1 Build 70 Halliburton H ALLI BURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 24 Company: Hilcorp Energy Company TVD Reference: Actual:BCU 24 @ 178.18usft((160.18 GL+18 I< Project: Beaver Creek Unit MD Reference: Actual:BCU 24 @ 178.18usft((160.18 GL+18 k Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 24 Survey Calculation Method: Minimum Curvature Wellbore: BCU 24 Design: BCU 24 WP6.0 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +EI-W Northing Easting DLS Vert Section (usft) (0) (0) (usft) usft (usft) (usft) (usft) (usft) 8,518.25 9,300.00 0.00 131.96 8,696.43 8,518.25 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 9,303.67 0.00 131.96 8,700.10 8,521.92 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 Tyonek 9,400.00 0.00 131.96 8,796.43 8,618.25 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 9,500.00 0.00 131.96 8,896.43 8,718.25 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 9,600.00 0.00 131.96 8,996.43 8,818.25 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 9,700.00 0.00 131.96 9,096.43 8,918.25 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 9,800.00 0.00 131.96 9,196.43 9,018.25 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 9,900.00 0.00 131.96 9,296.43 9,118.25 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 10,000.00 0.00 131.96 9,396.43 9,218.25 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 10,100.00 0.00 131.96 9,496.43 9,318.25 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 10,200.00 0.00 131.96 9,596.43 9,418.25 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 10,300.00 0.00 131.96 9,696.43 9,518.25 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 10,400.00 0.00 131.96 9,796.43 9,618.25 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 10,500.00 0.00 131.96 9,896.43 9,718.25 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 10,600.00 0.00 131.96 9,996.43 9,818.25 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 10,700.00 0.00 131.96 10,096.43 9,918.25 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 10,800.00 0.00 131.96 10,196.43 10,018.25 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 10,900.00 0.00 131.96 10,296.43 10,118.25 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 11,000.00 0.00 131.96 10,396.43 10,218.25 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 11,100.00 0.00 131.96 10,496.43 10,318.25 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 11,200.00 0.00 131.96 10,596.43 10,418.25 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 11,300.00 0.00 131.96 10,696.43 10,518.25 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 .11,400.00 0.00 131.96 10,796.43 10,618.25 -1,869.90 , 1,958.32 . 2,432,155.90 319,393.50 0.00 2,707.68 Total Depth:11400'MD,10796.43'TVD-5 1/2" 9/29/2014 1:57:42PM Page 5 COMPASS 5000.1 Build 70 Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 24 Company: Hilcorp Energy Company TVD Reference: Actual:BCU 24 @ 178.18usft((160.18 GL+18 k Project: Beaver Creek Unit MD Reference: Actual:BCU 24 @ 178.18usft((160.18 GL+18 k Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 24 Survey Calculation Method: Minimum Curvature Wellbore: BCU 24 Design: BCU 24 WP6.0 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +EI-W Northing Easting -Shape (0) (°) (usft) (usft) (usft) (usft) (usft) BCU 24 Section Lines-1500'offset 0.00 0.00 -0.92 -4,016.05 -2,974.36 2,430,086.36 314,428.19 -plan misses target center by 5750.37usft at 3200.00usft MD(2945.12 TVD,-776.03 N,752.56 E) -Polygon Point 1 -0.92 6,627.73 5,080.22 2,436,634.65 319,610.40 Point2 -0.92 -1,651.58 5,133.02 2,428,355.52 319,535.03 BCU 24 BC_B4ST Tgt wp3 0.00 0.00 5,253.18 -1,582.02 1,638.13 2,432,448.70 319,077.80 -plan hits target center -Circle(radius 50.00) BCU 24 Shallow Tgt wp3 0.00 0.00 3,020.18 -812.48 782.21 2,433,231.40 318,233.90 -plan misses target center by 7.35usft at 3288.24usft MD(3023.30 TVD,-806.11 N,780.29 E) -Circle(radius 50.00) BCU 24 Section Lines 0.00 0.00 -0.92 -4,016.05 -2,974.36 2,430,086.36 314,428.19 -plan misses target center by 5750.37usft at 3200.00usft MD(2945.12 TVD,-776.03 N,752.56 E) -Polygon Point 1 -0.92 5,151.13 6,603.26 2,435,134.65 321,110.40 Point 2 -0.92 -128.53 6,609.62 2,429,855.53 321,035.03 Point 3 -0.92 -128.99 1,329.95 2,429,936.80 315,755.98 Point 4 -0.92 5,150.69 1,323.59 2,435,215.94 315,831.35 BCU 24 Mid Tgt wp3 0.00 0.00 7,816.18 -1,869.90 1,958.32 2,432,155.90 319,393.50 -plan hits target center -Circle(radius 50.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 3,200.00 2,945.12 9 5/8" 9-5/8 12-1/4 11,400.00 10,796.43 51/2" 5-1/2 8-1/2 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (usft) (usft) Name Lithology 6,664.28 6,068.10 UBC3 7,866.20 7,264.10 B18 5,580.53 5,058.10 B2 5,795.70 5,249.10 B4 3,280.11 3,016.10 SHALLOW GAS 8,380.67 7,777.10 B24 8,523.67 7,920.10 B28B 8,801.67 8,198.10 B30 9,303.67 8,700.10 Tyonek 9/29/2014 1:57:42PM Page 6 COMPASS 5000.1 Build 70 Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 24 Company: Hilcorp Energy Company TVD Reference: Actual:BCU 24 @ 178.18usft((160.18 GL+18 I< Project: Beaver Creek Unit MD Reference: Actual:BCU 24 @ 178.18usft((160.18 GL+18 k Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 24 Survey Calculation Method: Minimum Curvature Wellbore: BCU 24 Design: BCU 24 WP6.0 Plan Annotations — --- ----_---_---_ ------ ---- _— _ __ Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 3,284.72 3,020.18 -804.91 779.18 Start Dir 3°/100':3284.72'MD,3020.18'TVD 3,366.29 3,092.53 -831.40 805.94 End Dir :3366.29'MD,3092.54'TVD 5,800.29 5,253.18 -1,582.02 1,638.13 Start Dir 2°/100':5800.29'MD,5253.18'TVD 6,921.02 6,322.52 -1,790.06 1,869.07 End Dir :6921.02'MD,6322.52'TVD 8,169.72 7,566.46 -1,862.63 1,950.19 Start Dir2°/100':8169.72'MD,7566.47'TVD 8,419.75 7,816.18 -1,869.90 1,958.32 End Dir :8419.75'MD,7816.18'TVD 11,400.00 10,796.43 -1,869.90 1,958.32 Total Depth: 11400'MD, 10796.43'TVD 9/29/2014 1:57:42PM Page 7 COMPASS 5000.1 Build 70 2 1 m 0L F. L m ac m_ L J o 4 > ii I 1 v Em c WN 11) 2 O R L c a c i—> 0• d 2 0 � 3 � a 22 ^ O N IZT W O Ccoo CC I 0 G O Cti T Oco CL m C _ T O N ^ itZ w • U ' Y E b E O 0.. m to co , N ra CV M J L =,4 Il .E. O CtS O 3 0 0 .00 N Y to 0 v 1� %am MO = U r L. co LD it W 3 O 0 �' 106 V ^� i O d 3 0 03 LL Q ■ C ' 41 L o r r=co N c o 3 :11- 0• = M ,- 0 N CD N r at ++ Aa) 0 �,, O N aYi � � oU Q C ? ? N W �A ECi � N w W = o v c W CD \/ CD C 0M m N a00. c M 7 m O L. L L S 0t C y V p M m O 0 O 000 L a) L ° 3Oa 0 -: C) ♦+ E N L L L d' w3 •_v 0 y„L 8 c L ” y oo C� V d) a) a) N N `V .�.d Q Q :° c c a v' a o. CO CO W W M In < 0 y _ 7 ti g C C y C C N .2 0 r Its co > u) u) : E ct R (z) a 5 c o o U 3 v U �A ti o o W w 0 I 1 (n) u! O U) O U) U) U) V) 0 U) 0 0 N U) () N N U) U) U) = NCO CO U) U) (0 N U) 0 N U) 0 U) 0 U) 0 CO CO 0 U) $y CO O O O al CO O O O CO O O C) CO O CO O (O O C) O 0- 0_ 0_ 0_ 0. a. O L. d d d n. d 0_ Q. Q. 0. n. O O •,—( c xv C C C C C C y E 0 `O `0 0 .� `o o `o .4 0 `o s o o 0 0 0 0 0 'c0000 .450 .N V N V U .N U O m U 0000 co = OO _ co co co _ co co (lCOCU m E co LL LL ,03 O LL O U- O LL LL O LL U O LL LL u LL LL. •C a) O O N N O aQ) a) (1) CDa) a) w a) N ( a) N a0 a) a) O co 0 0 0 co 0 co 0 co O O U 0 0 co 0 0 ° u C C C C C C C C C C C C E a) O CO d a) CO N CO N CO CO a) CO N N CO O O O O E 6 coNQ 0 NQ ( 6 Q ( 2 O p_ O O C Q O CO O 3 - N a) O _ N _ a _ a) a _ a) a) _ N (1) a) a) a) Cl) W 0 0 0 W U 0100100 WO U W U 0 0 0 0 y ti CO U) N- U) O 0) N- N— CD0) M CO M' O n N— M N`- a) 1---- V CO O U) U) V O c} NCO O d' CO N V' V 6) CO N- V N- U) U) (.13 0 CO r M- CO (O r N N N U) U) V. U) (CO 4O U) O (O CD N N N. U) n 6) O O) N N N N O) 6 M U) ,al R N N 0) (O N N r r r CO U) r 'd' VL' U) N O LL U -OO CO N O O CO O) CO O O O O N O N- (O (0 V n O d- U) v v O O Mt N v O CO (3) N (O r h CO CO CO N (' U)N 6) O6 6) 6) CO 4 6) CO U) (O U) U) O) = .F'C. w r V CO CO 0 0 CO CO C) N CO N- d) N C') d' Cr d' N� (/) Q y r r 0) N0 (C) 0 V 0 V 6) r 0 N N N 0) CO 0) O) O d a M V N M O O co" (O C) co- N CO' r N- N- N� N N N N 2c1)CI r r a CO U) M (O (O 6) 6) U) V 6) O (O CO N-- (O CO U) (O CO N C CO (O CO N CD U) (O CO O) r O) a N Cr 0 h 0 0 N� N O 6 U) O U) V U) (O U7 M N CCI 4 N (N N C') C) CO N l�6=) N O O LO CO O) M co (O (O O N N Mt U) Q o y CO6N N O O O N- N Ns CO CO CO 6) r r 7a) W Q v r r r r r r r r r O cD v (n (() r "" O CD E . O O O 0 O) O 0 0 0 N- Co 0 O N 0 0 0 0 0 0 N ^ O O O O N O 0000. 0 O O O) O O O O O O Li = C t O 6 O O V LL') O 6 O O O O (n O (n O O O O o co Q 0 0 N- O O CO N O N O CO 0 O O CO 0 N O O O O N co y N N N N N— CO NM- NI— CV N sT P CO CO NNNN a y d 7 C') V C) C') O O C') U) M 6) M C') r U) U) U) M M C) C) co N o 6 7.3 co O O) M CO O U) M d' U) Mr 0) '1' V r (0 U7 O 6) CO N C E O V' N. O CO N O M r CO. r C) N� r r cr r r a- C) 4 0 N a o O V O O M O N W CO (() N M M U) (O (O O O U) r r r r r COCO (4 CO 0 U) U) 0) O) O 7 Cr T CO o E la ch O) co_ N 0 0 0 CO co..M O O co O N N N • r d1 d O C y 3 W x co 0 0 0 0 O) O O O O N- O 00 N O O O O O O }N D m 2 3 O O O O N 0 0 0000 O O moo0000 • Ft3 N 'p Q,N O UO O V UO UO O O O UO U 0 0 0 0 C a) N Ny O N— OO (ON ONOCOO OO COON OOOO N N N N N- CO N v N r N N v_ h CO CO N N N N EyU 0 — M V M M O O M UM O co- M UUUM M M M r ,-- 2. m U ES4D N Y Cl) w � d O C 0 r 0) T U) V O N _ V O a) CU _ ` 7, y 0 00 = 0 0 0 CO (3j m 2 u- CU m m 0 0 =O ' = V Z _O ce O_ { M_ _M _M CO U) 0 0 _O CO CO 0 LO LO LO N N N N N N 3 C C i `p D D M D D 0 0 0 m m D 0 0 0 0 0 0 U) = U) 6) Oo . = ,,, ,,, 9 UUUUUU U U 0 U U U U U U Ln Y O d m m m (0 m (0 m m 0 0 m m m m m m m 8c0, 88 m 1 ct (0 0 0 0 (6. O :" d U O O r M M CO CO CO CO CO O N N N N N N ' (� ii LO 0 CO 01 CD In 0 0 0 0 0 0 00000 0 0 0 0 0 0 » D D � > o coEC mmmmmm (0 (0 (0 (0 ( mmmmmm 0000 a (o .. N z (0 (0 (0 (0 r' 0 m O Cp Y O O r M M M (O (O (O (0 O M F\)) A U) U) U) Nt N+ 0 M Q M 2y r N N N N N (O 6) N C OV) 0 co tNi M . O) EEEEEE EEEEE CCCCCC CCCC O M •O d 0 V Y YYYYY YYYYY YYYYYY YYYY -0 J `G0 ai N E ': d UUUUUU UUUUU 000000 0000 E w O Q' N C'v Z Q > a) a) 0 ) a) a) a) a) a) a) 0 m 0 a) m a) N N N N N O. al Q V Q (a > > > > > > > > > > > > > > > > > > > > > a) ::+ y ami �' o d a@i a0i m N N N N a@i N N N N N ami N N N ami a@i ami ami I = y y C C U m m m m m m m m m m m m m m m m m m m m m m N I< UDeNO � 0) etZ o 0 U " U i W AI 0 CO Z o o) o C F— + y co„Y co co coco as Q co M u) O O O ci) c ci) cn + I + + O 0 0 0 U) 0 0 CO CL to F. n. Q. N to •o D m `ro U CL CO CO a) d' o a w N (0 c -o 0 •F+ o N s N O ` E g m63 a0i ro U a n a) m 0 L rn O o 0 Q) 03000 O CD 0 co 0 o CDro O y cn N w U N O CO J. co N o_ -O N L = N Z O 7 2L' 0 C ' C s- I C = 0 ' {� 0 0 0 0 Co a) a) a j 000 ,0 o U co p O O O 0 N W O N )0 t (` 0 F ^ LL 0 tl) U a, z U c0 i.L "i o a) a) ° w m N 9 Ce N 0 N N U 0 F O O 2- a N N 0 3 o ro Na) ro '- 0 0 0 N ro u ro .. •(/) N m ami o s m 0 J Q " m " E L. . J 0 � .N CD � 0 op V ,0 m V 0 0 il Ic N4 oaN � N a W0CA00 < 0) = I~ 0) : a 0. o 0 0 0 em+ o U > >> 0 0 s, 0 co > > y �� > > > > ? > > > 5 0 0 W W O M (O U o o N N N O 0) O (() O o > > > CO D D > > D ch U En U (O rn DD DO CO CO m c m m m m m U 0000 - 0000Dm o m• U U O_ c7 (O (0 co o (- 'V L6 m m m V L1.1D p n n D D n D D c) ch ri n cfl 0-5 "." LI mm m mmm mm mm DD D yW U U U U U U O c (O (o oO O) M V �i m m m CO m m J _ N N N CO-_ CO LC) 0) (O Cc C C 'C C 'C 'C 'C 'C C C c c C O Y Y YYYYYYYYYYY Y Y > 0 0 0 0 0 U 0 0 0 0 0 p 0 0 0 U > > > > > > N Nas co CU CI CU CU CU CU CU CU CZ CU CU CO D a) a) N U) m a) a) 0) a) d) N c) N N N 0 m m m m m m m m m m m CO m m m CO CO 4 10 '61 , 4 + * + + + 4 + * ,- 04 V' I I I N I C I II D U ill Q)> I o m o0 `411,41 o >- li ;7121 - ' Lo 2 at - I o CD . Ii I o a �1 I o a F . o .y LLJ / I I� — I �N m I ' I I I m I I D UI I I 0 I/o I O M W ? II o N 1 L... I \' I I I o Y II CD 12 NoJCa) o `v I Ici ; I I I Cr) ro a I I I o a) U Q iii AAi....._ �I I _ o to C p \ E,r'� I o oy � > p 'O 13 ` � `11 I I I r -rd CD co O /,�1 Q ro I 1 I I NV L1 U I 1 I I L ` N N C I Z O f' I I I I o C {� O m O > I I 0 I o L j" C O I 1 I I N O d ' U I I I 1 T_ a I I I Ito '(/y■�1 Q N 6I I I to IX O _ O.) caO CA o I I ro e- C NO p N I I o • N •N ro C O C) O ® °) OD CD 14 .o o ._ (ui/}�sn opt) uoigoJedas as}ua° oT aqua° CO I = O p N 2- 'C O C Qb Cl) o U O E > 0 O V >, 0 U U > > a = a O 0 CL CO 6 > > x., 0 0 0 0a O O O O 0 0 � C > > > > > >> � Cr Cr O _ CO (O -, OO 0) CO N CO 0 CO O I) 0 0 W Pa D > > > CO > > > > > M U (>n U (>o rn C..1 0 03003 CCICCOOmmmmmm0o0o00 O Z O ..- M (O CO Op O Cr N N CO CC CO CC. M m nF...II UJ 0 0 0 0 0 0 0 0 0 0 (+j CO LC; LL) O 1+1 W 00 CO CO CO m CO CO CO CO m m CCI CO CO ° m J O c- M (. O 00 O N N N (.„.i— M (n (o (O O C E •E •E E 'E E E C V C C E E E E Q 0 0 0 0 0 0 0 0 0 U7 O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Y 0 0 0 0 UB 0 0 (6 (6 (0 (6 (6 (0 (6 (0 (0 CO CO (6 (6 0 (6 (0 0 N N N N N N N N N N N Cl) Cl) Cl) N N 0 m CO m CCI m m m m m CCI m CO m m m 00 CO _.._ O O —O - O 0 -_.-- _ _---i_---_ _ 0 0 0 _ O0 LD0 o/� . (0 _ O O (n a. _ � ?J }' - a d' o u. N - co vL___ - igo CO ca o I N c - z5 - o N o 0 _ - Q_ - YCO -- = 1 o U0 - U) O E - o o 0 O L - M . �..1 d as o cca EC L. O O _ A ++ 0 _ O C) ... c6 O C - O O. -...--------- -- ------ ------ y N---- —o a al 0 • N o ,. J _ .a I I I I I I I I I I mil , . I I I I I I I I. I I I I I - O E J 0 O0 r u0 ) N 0 r 0 1.0 N 0 CZ m _ c O co N. co co M (UV 09z)Jo}oe- uogeaedos N O c°Cb IC c a II Maximum Anticipated Surface Pressure Calculation 8-1/2" Hole Section Hi cora Beaver Creek#24 Beaver Creek Unit MD TVD Planned Top: 0 0 Planned TD: 11400 10796 Anticipated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG Grad Shallow Gas 3016 1300 WATER/GAS 8.3 0.431 B2 5058 2300 WATER/GAS 8.7 0.455 B4 5249 2300 WATER/GAS 8.4 0.438 UBC3 6068 2850 WATER/GAS 9.0 0.470 B18 7264 3400 GAS 9.0 0.468 B24 7777 3500 GAS 8.7 0.450 B28B 7920 3600 GAS 8.7 0.455 B30 8198 3600 GAS 8.4 0.439 Tyonek 8700 3600 GAS 8Q„ 0.414 TD 10796 3800 GAS 6.8 i 0.352 &- / Offset Well Mud Densities Well MW range Top(TVD) Bottom(ND) Date Beaver Creek 1B 9.2-9.9 ppg 5,200 10,900 2014 Beaver Creek 23 8.8-11.4 ppg 400 10,353 2014 Beaver Creek 13 8.5-10.4 ppg 0 10,182 2003 Beaver Creek 14A 9.0-9.4 ppg 5,000 9,450 2014 Beaver Creek 7A 9.0-9.3 2,400 8,929 2014 Beaver Creek 12A 9.0-9.4 4,500 9,578 2014 Assumptions: 1. Fracture gradient at shoe is estimated at 0.65 psi/ft based on field test data. 2. Maximum planned mud density for the 8-1/2"hole section is 10.5 ppg. 3. Calculations assume"Unknown"reservoir contains 100%gas(worst case). 4. Calculations assume worst case event is 100%evacuation of wellbore to gas. Fracture Pressure at 9-5/8"shoe considering a full column of gas from shoe to surface: 2945(ft)x 0.65(psi/ft)= 1914 1914(psi)-[0.1(psi/ft)*2945(ft)]= 1620 psi MASP from pore pressure(unknown gas sand at TD,at 8.4 ppg,encountered while drilling) 10,796(ft)x 0.352(psi/ft)= 3800 psi 3800(psi)-[(2/3)*0.1(psi/ft)*10796(ft)]+[(1/3)*0.352(psi/ft)*10796(ft)]= 1813 psi MASP from pore pressure during production mode(Complete evacuation to gas) 10,796(ft)x 0.352(psi/ft)= 3800 psi / 1 3800(psi)-[0.1(psi/ft)*10796(ft)]= 2720 psi Summary: 1. MASP while drilling 8-1/2"production hole is governed by pore pressure and evacua • of 2/3 wellbore to gas at 0.1 psi/ft. Calculation & Casing Design Factors Beaver Creek Unit DATE: 9/29/2014 WELL: Beaver Creek#24 FIELD: Beaver Creek DESIGN BY: Monty M Myers Design Criteria: Hole Size 12-1/4" Mud Density: 8.8 ppg Hole Size 8-1/2" Mud Density: 11.5 ppg Hole Size Mud Density: Drilling Mode MASP: 1813 psi (see attached MASP determination &calculation) MASP: Production Mode MASP: 2720 psi (see attached MASP determination &calculation) Collapse Calculation: Section Calculation 1 Normal gradient external stress (0.435 psi/ft) and the casing evacuated for the internal stress Casing Section Calculation/Specification 1 2 3 4 Casing OD 9-5/8" 5-1/2" Top(MD) 0 0 Top(TVD) 0 0 Bottom (MD) 3,200 11,400 Bottom (TVD) 2,945 10,796 Length 3,200 11,400 Weight(ppf) 40 17 Grade L-80 P-110 Connection BTC DWC/C HT Weight w/o Bouyancy Factor(lbs) 128,000 193,800 Tension at Top of Section (lbs) 128,000 193,800 Min strength Tension (1000 lbs) 916 546 Worst Case Safety Factor(Tension) 7.16 2.82 Collapse Pressure at bottom (Psi) 1,281 4,696 Collapse Resistance w/o tension (Psi) 3,090 7,480 ix Worst Case Safety Factor(Collapse) 2.41 1.59 MASP (psi) 971 2,720 Minimum Yield (psi) 5,750 10,640 / Worst case safety factor(Burst) 5.92 3.91 1/ TRANSMITTAL LETTER CHECKLIST WELL NAME: C2 ' Z Z � CJtS(vz�� PTD: 2-( `7/ /7 Z-- Development Service Exploratory Stratigraphic Test _Non-Conventional FIELD: ,,G L (G—{' OOL: 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 Well Logging also required for this well: gg g Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. r ( 4i/X/ /0 Revised 4/2014 E To 2 co 0 o -on 0 N 00) ° p c co So) N U L Q) C Q 0 a) Ii m C O N a o N O U O d w p ° 0 O aj a) `t a co O C C N E N O U T — o N.. a) > L @ @ a� E ° y, c w U) 0) -0 a) `O: N CO 0 ° o U 0 O Q ° p nc msa) E 0 E E O rr) a P 0) m 0) -o a) o O N C ° N a N a n a) > 0 `0) @ N L n _ a CO N- 2 O °) o 0 CD 3 o E m N- d so N O C N 0 .� 0) y L°.. O a N c a) E E 3 c O ° 3 0 7 2 .-C O2 — Y 7 to o co > C w N .c 0 co aj T -5 N 0) CO o CO 0) 0 -C — H -p .N — O 3 O _ C -U O C O ° > C a) O E C p _ co co N Uo co p Y a O o 0) ° a O Ti)0 0 E. o o -p M — O 2 c E N E 2 a ° c6 (O a) 3 N LU a W O O CO C 0. 0) J L a) c C O) O a) N 0 m O a) 0o co U O CO O N '3 c n o „.,c) > ° u) a v > c o c. .5) L O 7 O O O U Q °) N 0 V M 0 p a N a) ' o a) " O N 3 L ° 3 -0 oo c a Z co W 0) o v (u a_ (0 v Q N c m ami CO C ai '( w a c a) a E a v YO N .c- -0 a �v°i a) C • : b a a m a) a 3 0 -0 @ o C 0 a) .c 0 O •- 0 U co C0 O ir)0 O C N a) O (n @ N 9 CO O O N Ct M U C N CO 'a T a) O co r co m "0 L @ O L n 0 ` a) co — w U 3 a) M ° —O U) _ a) @ To Q Q m o m Q n. a N 0) cr c L .o m' o w _ Ca 0 Y o .N o y n co o .N -0 .- -o ui CO 2 co LL w ° To r Cr_ 0 3 w . 'a • >, N a i° n Q 0 -°0 3@ .0 E Q C Et O N 3 0 ° E - -Y 0 a) 3 c L 0 ,_ ._ o_ o ° rn a`)2 41 0 _ U .N U r U. 7 o L ° - U > To co O in a) 73 ° N., O rn 'm N N g x ° E d E C� a) w N a D E = 0 ° o N o .- CO E -c u °CO o ° c °O Z E > N C mN N O N a L N .E cp �O c0 d O c c C N j C M ° Q C W L O ° O In m Lo N F 0) @ O @ N CO Q CO N N CO O . N O (� w co H L... 0 2 Q) N LU 0 co C Co d U) 2 U) 2 0 = 2 d d O N 0 c - > 0o w ° u) 0 C0 ci N N N N N N N N N N N N N N N N N N N co N N N N N co co co ° < a) a) a) a) a) a) a) a) a) a) a) a) < < < Q a) a) a) a) a) a) a) < ° a) a) a) a) a) a) o < a) a) < < < n z >- >- >- >- >- >- >- >- >- >- >- >- z z j z >- >- >- )- >- >- >- z >- >- >- >- > >- >- z z >- >- z z z 7- T _ N O @ \. N -OUmE E a) ° N C O 0 p U .y > n E 7 Q L o d E o HI >, U 3 o Q o co 0 a) co U 0 C N C O Q O ,- y 0 a) E co (0 Q -co O O a) coo N N m O. O O O N O C > � O N a (6 U V N N ° U 7 O v c J N c0 7 c 7 ��J °] c — ° ° " N -0 't c E LaI ° O 72 cn O > N O O) C � O co "p O = N N °' 0 "0 0 0 a o N C -O O ° 0- O C a) CO O O O) N L N C a) O) .. a) N O ‘— C U > 0 O N N N Q O O O O° 4 ct E E — "0 c C E @ N O M C C N H C O o2$ C ° O) N L ,- '..E C c ° c cn 3 0 m a a o uS d o 3 > N N > o N O O -o U OU @ N O O Q c a) c -O U O C a) .N Q .c6 O N '0 O Y uNi ° o ° o m o 0 0 ° m m o ° a w 0 E ° 0 0 ° > .0 0 0 ° c E m — m i o O E 7 3 0 2 a) TO 3 '= ° •c E 0 CO J a) o a N 0 L (° m a) L L -0 co O 7 N -0 O ` •C �" 0 N O '- 0) On N °- n 3 _o .0 O >, 3 c E J6. c N N@ n n@ 3 3 a°) M a) a o -0 '� m 3 c 2 o n 0 a `) n a) m o 3 ° t ° o W U 0 y O c , ,..,•- "O > 0 `a _0 _0 O c6 o c a) O O c a• a N O 0) C '0 N a) cn -p O a) O o o ° ° E o , ° o o N E ° O E L o ° fl N c ° a "0 o N — O 7 7 a C C II) ° d 2 a) a) _ '0 a) 2 -p O E 01 O cn _ 7 C O 0 <0.6 L N ° O O O m N On, La ./) a L N 0) a O O 3 aO CD CO p ° o) C U 3 N "0 N O N C L am N c � O Cl) >, N a) a) a) 3 c -0 p) c m Q Q N c .--CO N L 7 p_ .0 N U o ,0 a) N T : a) _ n n 0 _ L.L O _co N N N N ca a O L N L 0 c N •c 0 -co° o '� m L 3 E "O 0 co C 0 ° U) C a) c 0 N O N 7 U) U6 UO d O O E U 3 7 0 o 0 _ ° ° _ 0 � ° 2 O _ c _U O N O U c I," 0 C 3 U U U o O o o .0 00 ° ° N O C U a) 0 0 = -° O "o O V) a E '3 a) C ,0, a) 0D U (/� J LU ° c O O O .0 O O n O 7 U > > 3 7 ° 7 ° m W W ° L. a E ° 0 ° Y I 0 m 'E a) a) a) 7 -00 n n a`) a`) o ° 3 E o 0 n 2 2 2 m -g 0 as -o0 C O O -c O - a aa) co co '5N) U)) o I 0 0 c a J 0 U) ` O O a a 0 <7C1_ z U U) 0 0 0 U < ) < ' 00:10:105L') 2 0 0 cn cn 0 W a O N M V c0 CO N- O 0) O N M V cf) (0 r o0 0) O N M V CL) (O 1� O O I EO — N co d co CO I,. CO 0) 0 CN N— aD •- N N N N N N N N N N o') c•) c+) C) M M C) C+) C) cq V U ,t- ‘- V V M_ a) O C rCD ea 0 O 0 w ( U C0 CO 0' CV ° 0 0) CI 7 CI O to H W s- (a O C O O O-- a O. 't ° J N -2 ° O W O E a o rn a -J 0 a a. o 0 ° d l a a CO to Q c9 ,..0 � Q cn Davies, Stephen F (DOA) From: Monty Myers <mmyers@hilcorp.com> Sent: Wednesday, September 03, 2014 6:54 AM To: Davies, Stephen F (DOA) Cc: Schwartz, Guy L (DOA) Subject: RE: BCU 25 Permit to Drill Application (PTD # 214-132): Questions Good morning Steve. I named the well Beaver Creek#25 and left the "Unit" unit out on the well name because the BLM had issues with#23 and #24 when I submitted their permit to them with "Unit" in the name. For consistency, I should have named it Beaver Creek Unit#25 on the 10-401. Great catch on the 9675' depth! That was the old depth of the original plan and should have been modified to the correct depth of 8200'. MW will still range from 9-10 ppg throughout this hole section. Thank you! If you have any more questions, please let me know. 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: Tuesday, September 02, 2014 5:30 PM To: Monty Myers Cc: Schwartz, Guy L (DOA) Subject: BCU 25 Permit to Drill Application (PTD # 214-132): Questions Monty, 1. Is the actual name/number of this proposed well Beaver Creek#25 or Beaver Creek Unit#25? 2. On page 30,the mud properties for the 8-1/2" hole section is given as: MD Mud Weight 3500'—9,675' 9.0—10.0 The TD of the well on Form 10-401 and in the directional survey is given at 8,200' MD. Please let me know the correct depth and mud weight ranges for this section of the planned well. Thanks, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 1 (----- - _ ,_, _S t =_— ^7� t — ---- ---- • � C \ E, �� 1 �L.1N PAR-NJ,' Clnu1-ym --- 333 Wes S e v n r Avenue Ancho age Alako ? .53'-3572 Mc 907 2I9 4; Monty Mack Myers Drilling Engineer Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: Beaver Creek Field, Beluga Gas Pool, Beaver Creek#24 Hilcorp Alaska, LLC Permit No: 214-112 (revised) Surface Location: 1127' FNL, 1645' FWL, Sec. 34, T7N, R10W, SM, AK Bottomhole Location: 2361' FSL, 1539' FEL, Sec. 34, T7N, RlOW, SM, AK Dear Mr. Myers: Enclosed is the approved application for permit to drill the above referenced development 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, 2letiPtex,2,74,‘__ Cathy Fr. Foerster Chair DATED this (oa y of September, 2014. STATE OF ALASKA RECEIVED A .A OIL AND GAS CONSERVATION COM JN SEP 0 3 2014 PERMIT TO DRILL - REVISION 20 AAC 25.005 A�nn _ 1 a.Type of Work: 1 b.Proposed Well Class: Development-Oil ❑ Service- Winj ❑ Single Zone 0 . 1 c.Specify if tvel1Ts'p cd . Drill 0• Lateral ❑ Stratigraphic Test ❑ Development-Gas E• Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates 0 Redril❑ Reentry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket 0 Single Well ❑ 11.Well Name and Number: Hilcorp Alaska,LLC Bond No. 022035244 • Beaver Creek#24 ' 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive,Suite 1400,Anchorage AK 99503 MD: 9,675' - TVD: 9,080' • Beaver Creek Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Beluga Gas Surface: 1127'FNL,1645'FWL,Sec 34,T7N,R1 OW,SM,AK A028083' Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 2102'FNL,2559'FEL,Sec 34,T7N,R10W,SM,AK NA 9/21/2014 Total Depth: 9.Acres in Property: 14. Distance to Nearest Property: 2361'FSL,1539'FEL,Sec 34,T7N,R1 OW,SM,AK 1920 acres(A028083) 2569'FEL,2131 FNL 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 179.2 feet . 15.Distance to Nearest Well Open Surface: x-317464.359 • y-2434055.893 . Zone-4 GL Elevation above MSL: 160.6 feet• to Same Pool: 1,200' 16.Deviated wells: Kickoff depth: 2,000 feet . 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 27 degrees 4 Downhole: 3600 psi , Surface: 2688 psi 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks _ Hole Casing Weight Grade Coupling Length _ MD TVD MD TVD (including stage data) Cond 16" 109 X-56 Weld 80' Surf. Surf. 80' 80' r Driven 12-1/14" 9-5/8" 40 L-80 BTC 3500' Surf. Surf. 3,500' - y_" 3 LI(cv 305.3bb1/1713.9ft3 8-1/2" 5-1/2" 17 P-110 DWC/C HT 10,808' Surf. Surf. 9,675' - 9,080' 4 365.2bb1/2050.4ft3 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat 0 BOP Sketch 0 Drilling Program 0 Time v.Depth Plot 0 Shallow Hazard Analysis❑ Diverter Sketch 0 Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements0 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Monty Mack Myers Email mmyers@hilcorp.com Printed Name Monty Mack Myers Title Drilling Engineer Signature —"---N • Phone (907)777-8431 Date 9/3/2014 Commission Use Only Permit to Drill API Number: , C. Permit Apnrr'"" See cover letter for other Number: tV.(-1\2 CZE`QSfcO 50-0.n-- '1���-L Date: �-�7� -20\� requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: Other: O� s` P S Samples req'd: Yes 0 No Q• Mud log req'd:Yes ElNo a H2S measures: Yes❑ No lli Directional svy req'd:Yes pi No❑ �' / An �� Spacing exception req'd: Yes El Nog. Inclination-only svy req'd:Yes❑ No Er 7'�✓ CBL APPROVED BY y Approved by9 . COMMISSIONER THE COMMISSION Date:q—( _-/¢ �':./�n n A Submit`Form and Form 10-401(Revised 2012) Thisbvel 'nIR`IS f r from the date of approval(20 AAC 25.005(g)) /�/,Q�/ttachments in Duplicate C s'(C 7 .r, ,s.N 2. zi. /V. STATE OF ALASKA RECEIVED P :A OIL AND GAS CONSERVATION COMA ON PERMIT TO DRILL REVISION AUG 18 2014 20 AAC 25.005 �yE1 1a.Type of Work: 1 b. Proposed Well Class: Development-Oil ❑ Service- Winj ❑ Single Zone ❑ 1 c.Specify if well i ` for: Drill ❑✓ Lateral ❑ Stratigraphic Test ❑ Development-Gas Q Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redril ❑ Reentry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Q Single Well ❑ 11.Well Name and Number: Hilcorp Alaska, LLC Bond No. 022035244 Beaver Creek#24 3.Address: 6. Proposed Depth: 12. Field/Pool(9: 3800 Centerpoint Drive,Suite 1400,Anchorage AK 99503 MD: 9,675' TVD: 9,080' Beaver Creek Field 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): Beluga Gas Surface: 1127'FNL, 1645'FWL,Sec 34,T7N, R1OW,SM,AK A028083 Top of Productive Horizon: 8.Land Use Permit 13.Approximate Spud Date: 2102'FNL,2559'FEL,Sec 34,T7N,R1OW,SM,AK NA 9/21/2014 Total Depth: 9.Acres in Property: 14. Distance to Nearest Property: 2361'FSL, 1539'FEL,Sec 34,T7N, R1OW,SM,AK 1920 acres(A028083) 2569'FEL,2131 FNL 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10. KB Elevation above MSL: 179.2 feet 15. Distance to Nearest Well Open Surface: x-317464.359 y-2434055.893 Zone-4 GL Elevation above MSL: 160.6 feet to Same Pool: 1,200' 16. Deviated wells: Kickoff depth: 2,000 feet 17.Maximum Anticipated Pres in psig(see 20 AAC 25.035) Maximum Hole Angle: 27 degrees Downhole: 3600 psi �/ Surface: 2688 psi 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD /TVD MD TVD (including stage data) Gond 16" 109 X-56 Weld 80' Surf. ,irf. 80' 80' Driven 12-1/14" 9-5/8" 40 L-80 BTC 3500' Surf. `1 . 3,500' 3,263' 305.3bb1/1713.9ft3 8-1/2" 5-1/2" 17 P-110 DWC/C HT 10,808' Sur47 urf. 9,675' 9,080' 365.2bb1/2050.4ft3 'v 19. PRESENT WELL CONDITION SUMMARY(To be complet for edrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): I Eff ct.Depth MD(ft): Effect. Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural ii Surface j iC•c- Intermediate Production Liner / Perforation Depth MD(ft): ,.. Perforation Depth TVD(ft): 20. Attachments: Property Plat 0 $O Sketch El Drilling Program ❑✓ Time v.Depth Plot El Shallow Hazard Analysis Diverter Sketch ❑✓ Seabed Report ❑ Drilling Fluid Program 2 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Monty Mack Myers Email mmyershilcorp.com Printed Name Monty Mack Myers Title Drilling Engineer Signature --~' • Phone (907)777-8431 Date 8/18/2014 Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number:2\'-\\2 50- Date: requirements. Conditions of approval : If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: ❑ Other: Samples req'd: Yes❑ No❑ Mud log req'd:Yes❑ No❑ H2S measures: Yes ❑ No❑ Directional svy req'd:Yes❑ No❑ Spacing exception req'd: Yes❑ No❑ Inclination-only svy req'd:Yes❑ No❑ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: &R t /l N Submit Form and Form 10-401 (Revised 10/2012) Th i ♦va4d o t s from the date of approval(20 AAC 25.005(8)) Attachmentss in Duplicate • Monty Myers Hilcorp Alaska, LLC II Drilling Engineer P.O. Box 244027 Anchorage,AK 99524-4027 REC I IV E© Email mmyers@h ilcorp.com Itilcorp Alaska,LLC. AUG 182014 August 18, 2014 Acle Commissioner Alaska Oil &Gas Conservation Commission 333 W. 7th Avenue Anchorage,Alaska 99501 Re: Beaver Creek (BCU)#24—Revised PTD Dear Commissioner, This is a revision to the previously submitted and approved PTD for Beaver Creek#24. The major change to this PTD / is the SHL for the well.This change was necessary to accommodate 3 wells on the eastern side of the pad as opposed to the two that were already submitted for approval.A future well will be place at the southeastern end of the pad. Other changes include updated directional plan version 4.0 and revised cement volumes. Beaver Creek#24 is a south easterly step-out appraisal well of the lower and middle Beluga gas sands on the eastern flank of the field between the BCU 13 and BCU 6 wells.The base plan is a 9,675'"S-turn"wellbore with a shallow kickoff around 2000', building to a tangent of 27 deg,then dropping back to vertical at 8,361' MD. • Drilling operations are expected to commence approximately September 21st,2014. / The Saxon Rig#169 will be used to drill the wellbore then run casing and cement. Surface casing will be run to 3,500' MD/3,263'TVD and cemented to surface to ensure protection of any shallow freshwater resources. Cement returns to surface will confirm TOC at surface. If cement returns to surface are not observed,a Temp log will be run between 6—18 hrs after CIP to determine TOC. Necessary remedial action will then be discussed with AOGCC and BLM authorities. All waste&mud generated during drilling and completion operations will be hauled to the Kenai Gas Field G&I f facility for disposal/beneficial reuse depending on test results. General sequence of operations: 1. MOB Saxon Rig#169 to well site 2. N/U 21-1/4"x 2M diverter. 3. Drill 12-1/4" hole to 3500' MD. Run and cmt 9-5/8"surface casing. 4. N/D diverter, N/U &test 11"x 5M T3-Energy BOP. 5. Drill 8-1/2" hole section to 10,808' MD. Perform Wiper trip. 6. POOH laying down drill pipe. 7. Run and cmt 5-1/2" production casing. 8. N/D BOP, N/U temp abandonment cap, RDMO. Hilcorp Alaska, LLC Page 1 of 2 Monty Myers Hilcorp Alaska, LLC Drilling Engineer P.O. Box 244027 Anchorage, AK 99524-4027 Tel 907 777 8431 Email mmyers@hilcorp.com Hikorp Alaxka,LLC Reservoir Evaluation Plan: 1. Surface hole:GR+Res LWD. 2. Production Hole:GR+Res+Den/Neu LWD. 3. Mud loggers from surface casing point to TD. 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 2 of 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION I� �`I' APPLICATION FOR SUNDRY APPROVALS ,Y, -'( t f 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well❑ Change Approved Program ❑✓ Suspend❑ Plug Perforations El Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re-enter Susp.Well El Stimulate ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill mber. Hilcorp Alaska,LLC. Exploratory ❑ Development Q 214112 3.Address: Stratigraphic ❑ Service ❑ 6.API Nu •er. 3800 Centerpoint Dr.,Suite 1400,Anchorage AK 99503 50-13 0639-00-00 7.If perforating: 8.Well Name and mber. What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No ❑✓ -eaver Creek Unit(BCU)#24 9.Property Designation(Lease Number): 10.Field/Pool(s): A028083 Beaver Creek Field/Beluga Gas Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft: 'lugs(measured): Junk(measured): 80 80 80 '$ Casing Length Size MD TVD Burst Collapse Structural Conductor 80 16 80 \(j° 1 80 N/A N/A Surface ({) ° Intermediate Production ( Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Packers and SSSV Type: -ackers and SSSV MD(ft)and TVD(ft): 12.Attachments. Description Summary of Proposal ❑ X13.Well Class after proposed work: Detailed Operations Program ❑✓ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 2Service 0 14.Estimated Date for t3 ' 15.Well Status after proposed work: 8/21/2014 Commencing Operations: Oil ❑ Gas 0 WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ 0 GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to t • best of my knowledge. Contact Monty M Myers Email mrmlyerS@hilCOrp.COm Printed Name Monty M Myers Title Drilling Engineer Signature Phone 907.538.1168 Date 1. • 8/15/2014 _ COMMISSION USE ONLY Conditions of approval: Notify Commission so at a representative may witness Sundry Number: \A--(-- ^ Plug Integrity ❑ BOP Test % Mechanical Integrity Test ❑ Location Clearance ❑ `-�\ Other: Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: nRliaG N� SubForm ane Form 10-403(Revised 10/2012) Apprp1 months from the date of approval. Attachmentss in Duplicate Hilcorp Alaska, LLC Beaver Creek #24 Drilling Program Beaver Creek Field ro d by: M sr My Version 0 July 10th, 2014 Beaver Creek#24 Drilling Procedure Hilcorp Energy Company Contents 1.0 Well Summary 2 2.0 Management of Change Information 3 3.0 Tubular Program: 4 4.0 Drill Pipe Information: 4 5.0 Internal Reporting Requirements 5 6.0 Planned Wellbore Schematic 6 7.0 Drilling/Completion Summary 7 8.0 Mandatory Regulatory Compliance/Notifications 8 9.0 R/U and Preparatory Work 11 10.0 N/U 21-1/4"2M Diverter 12 11.0 Drill 12-1/4"Hole Section 15 12.0 Run 9-5/8" Surface Casing 20 13.0 Cement 9-5/8" Surface Casing 23 14.0 BOP N/U and Test 26 15.0 Drill 8-1/2"Hole Section 27 16.0 Run 5-1/2"Production Casing 32 17.0 Cement 5-1/2" Production Casing 35 18.0 RDMO 38 19.0 BOP Schematic 39 20.0 Wellhead Schematic 40 21.0 Days Vs Depth 41 22.0 Geo-Prog 42 23.0 Anticipated Drilling Hazards 43 24.0 Saxon Rig 169 Layout 45 25.0 FIT Procedure 46 26.0 Choke Manifold Schematic 47 27.0 Casing Design Information 48 28.0 8-1/2"Hole Section MASP 49 29.0 Spider Plot(NAD 27) (Governmental Sections) 50 30.0 Surface Plat(As Staked) (NAD 27) 51 31.0 Surface Plat(As Staked)(NAD 83) 52 32.0 Directional Survey 53 BeaC #2 Drillingver Procedurereek4 Rev 0 Hilcorp Energy Company 1.0 Well Summary Well Beaver Creek#24 Pad&Old Well Designation Beaver Creek#24 is a grass roots well on BCU Pad#3 ' Planned Completion Type 5-1/2"Production tubing Target Reservoir(s) Beluga Planned Well TD,MD/TVD 9,675 MD/9,080' TVD PBTD, MD/TVD 9,555' MD/ 8,961' TVD Surface Location(Governmental) 1127' FNL, 1645' FWL, Sec 34,T7N, R10W, SM,AK ' Surface Location(NAD 27) X=317464.359,Y=2434055.893 Surface Location(NAD 83) X=1457485.525,Y=2433816.782 Top of Productive Horizon (Governmental) 2102' FNL,2559' FEL, Sec 34,T7N,R10W, SM,AK TPH Location(NAD 27) X=318521.33,Y=2433072.37 TPH Location(NAD 83) X=1458542.51,Y=2432833.20 BHL(Governmental) 2361'FSL, 1539'FEL, Sec 34, T7N,R10W, SM,AK BHL(NAD 27) X=319530.2,Y=2432240.3 BHL(NAD 83) X=1459551.39,Y=2432001.08 AFE Number 1412278D AFE Drilling Days 5 MOB, 22 DRLG AFE Completion Days AFE Drilling Amount $4,834,020 AFE Completion Amount $300,000 Maximum Anticipated Pressure (Surface) 1462 psi(Drilling) Maximum Anticipated Pressure (Downhole/Reservoir) 2688 psi . Work String 4-1/2" 16.6# S-135 CDS-40(Saxon Owned String) RKB—GL 179.2'(160.6+ 18.6) • Ground Elevation 160.6' • BOP Equipment 11"5M T3-Energy Annular BOP 11"5M T3-Energy Double Ram 11"5M T3-Energy Single Ram Page 2 Version 0 July, 2014 B Drillingeaver ProcedureCreek#24 Rev 0 Hilcorp Energy Company 2.0 Management of Change Information Hilcorp Alaska, LLC Hilcorp Encra Conway Changes to Approved Permit to Drill Date: July 10, 2014 Subject Changes to Approved Permit to Drill for Beaver Creek#24 File#: Beaver Creek#24 Drilling Program Any modifications to the Drilling&Completion Program will be documented and approved below. Changes to an approved APD will be c not Lathe A OGCC&BLM.. j I :JJ i �i —Z/•-/yam Date Procedure Change Approved Approved By BY Approval: Drilling Manager Date Prepared: Drilling Engineer Date Page 3 Version 0 July, 2014 B # Drillingeaver Procedure Rev 0 Hilcorp Energy Company 3.0 Tubular Program: Hole OD (in) ID (in) Drift Conn Wt Grade Conn Burst Collapse Tension Section (in) OD (in) (#/ft) (psi) (psi) (k-lbs) Cond 16" 15" - - 109 X-56 Weld 12-1/4" 9-5/8" 8.835" 8.679" 10.625" 40 L-80 BTC 5750 3090 916 8-1/2" 5-1/2" 4.892 4.767 6.050 17 P-110 DWC/C HT 10640 7480 546 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) All 4-1/2" 3.826 2.6875" 5.25" 16.6 S-135 CDS40 17,693 16,769 468k All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 4 Version 0 July, 2014 Beaver Creek#24 1111 Drilling Procedure Rev 0 Hilcorp Energy Company 5.0 Internal Reporting Requirements 5.1 Fill out daily drilling report and cost report on Wellez. • Report covers operations from 6am to 6am • Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area—this will not save the data entered, and will navigate to another data entry tab. • Ensure time entry adds up to 24 hours total. • Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. 5.2 Afternoon Updates • Submit a short operations update each work day to pmazzolini@hilcorp.com , lkeller@hilcorp.com ,mmyers@hilcorp.com and jbarrett@hilcorp.com 5.3 Intranet Home Page Morning Update • Submit a short operations update each morning by 7am on the company intranet homepage. On weekend and holidays, ensure to have this update in before 5am. Each rig will be assigned a username to login with. 5.4 EHS Incident Reporting • Notify EHS field coordinator. 1. This could be one of(3) individuals as they rotate around. Know who your EHS field coordinator is at all times, don't wait until an emergency to have to call around and figure it out!!!! a. John Coston: 0: (907) 777-6726 C: (907)227-3189 b. Mark Tornai: 0: (907)283-1372 C: (907) 748-3299 c. Thad Eby: 0: (907)777-8317 C: (907)602-5178 2. Spills: Kate Kaufman: 0:907-777-8329 C:907-244-8292 • Notify Drlg Manager 1. Paul Mazzolini: 0: 907-777-8369 C: 907-317-1275 • Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally • Send final"As-Run" Casing tally to mmyers@hilcorp.com and jbarrett@hilcorp.com 5.6 Casing and Cmt report • Send casing and cement report for each string of casing to mmyers@hilcorp.com and jbarrett@hilcorp.com Page 5 Version 0 July, 2014 B 11 Drillingeaver ProcedureCreek#24 Rev 0 Hilcorp EnergY Company 6.0 Planned Wellbore Schematic well Beaver CrBCS eek Unit PROPOSED PTD: 000-000 API: 50-000-00000-00 ,..,...r%R..6..114 CASING DETAIL Size Type Wt I Grade Conn. ID Top Btm I6" ;, } weight ## x Conductor c � " y�..41. '� _Driven L�" to Set 109 ' B-5G Weld 16" Surf , 80" .. • Depth b*, ",'1 9-5/8" Surf.Csg 40 L-80 BTC 8.835" Surf F 3500' • 8.8 ppg - `7S y 5-vr Prod Csg 17 P410 f4'3 r- D C 4.892" Surf •, 9,679" . 9.0 ppg•--10.G (r,3.) 74; HT 0-5,�8- i. Yrs • ks "' x *` ,P 0. �: Drilling Info .r°",, r Hole Section Casing MW Workstrirrg ..*4.', 4y '�+ _° 12-1/4" 9-5/8" 8.8 ppg • 4-1/2" ,:. , 8-1/2- 5-1/2" 9.D-9S ppg `-: 4-1/2" . `,-.e JEWELRY DETAIL '..Z,1* * Dpth I ID 1 OD Item "' r " 1 3000 14.892 [8S" Baker Swell Packer 8-1.1" .°tom, :, Hole ., jr' � .4 f-r,' r' ,.. ... ir.; k �"lt V ri 47 Aii, 5-112" - { PRTD-9.5,55*:PRTVD-6,961' TD-9,675`111,1)�9.060` Page 6 Version 0 July, 2014 B Drillingeaver ProcedureCreek#24 Rev 0 Hilcorp Energy Company 7.0 Drilling / Completion Summary Beaver Creek#24 is a south easterly step-out appraisal well of the lower and middle Beluga gas sands on the eastern flank of the field between the BCU 13 and BCU 6 wells. The base plan is a 9,675' "S-turn"wellbore •with a shallow kickoff around 2000',building to a tangent of 27 deg,then dropping back to vertical at 8,411' MD. Drilling operations are expected to commence approximately September 19th,2014. The Saxon Rig# 169 will be used to drill the wellbore then run casing and cement. • Surface casing will be run to 3,500' MD / 3,216' TVD and cemented to surface to ensure protection of any shallow freshwater resources. Cement returns to surface will confirm TOC at surface. If cmt returns to surface are not observed, a Temp log will be run between 6— 18 hrs after CIP to determine TOC. Necessary remedial action will then be discussed with AOGCC and BLM authorities. All waste & mud generated during drilling and completion operations will be hauled to the Kenai Gas Field G&I facility for disposal/beneficial reuse depending on test results. General sequence of operations: 1. MOB Saxon Rig# 169 to well site 2. N/U 21-1/4"x 2M diverter. 3. Drill 12-1/4"hole to 3500' MD. Run and cmt 9-5/8" surface casing. '/ 4. N/D diverter,N/U&test 11"x 5M T3-Energy BOP. 5. Drill 8-1/2"hole section to 9,675' MD. Perform Wiper trip. ' 6. POOH laying down drill pipe. 7. Run and cmt 5-1/2"production casing . 8. N/D BOP,N/U temp abandonment cap, RDMO. Reservoir Evaluation Plan: 1. Surface hole: GR+Res LWD. 2. Production Hole: GR+Res+Den/Neu LWD. 3. Mud loggers from surface casing point to TD. Page 7 Version 0 July, 2014 B #2 Drillingeaver Procedure Rev 0 Hilcorp Enemy company 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with the below AOGCC regulations. If additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to contact the Anchorage Drilling Team. • BOPs shall be tested at (2) week intervals during the drilling of Beaver Creek#24. Ensure to provide AOGCC 24 hrs notice prior to testing BOPs. • The initial test of BOP equipment will be to 250/4000 psi & subsequent tests of the BOP equipment will be to 250/4000 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 approved drilling permit and BLM sundry are posted on the rig floor and in Co Man office. Regulation Variance Requests: • Onshore Oil and Gas Order No. 1, Section III. D. 3. C. o Hilcorp requests approval to install a 3-1/8" 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. o Hilcorp requests approval to utilize flexible choke and kill lines in lieu of hard piping. Page 8 Version 0 July, 2014 Bea Drillingver ProcedureCreek#24 Rev 0 Hilcorp Energy Company Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure(psi) 12-1/4" • 21-1/4"x 2M Hydril MSP diverter Function Test Only • 11"x 5M T3-Energy(Model 7082)Annular BOP • 11"x 5M T3-Energy Double Ram Initial Test:250/4000 o Blind ram in btm cavity (Annular 2500 psi) • Mud cross 8-1/2" • 11"x 5M T-3 Energy Single Ram • 3-1/8"5M Choke Line Subsequent Tests: • 2-1/16"x 5M Kill line 250/4000 • 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 and Sundry. Page 9 Version 0 July, 2014 B Drillingeaver ProcedureCreek#24 Rev 0 Hilcorp Energy Company 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@blm.gov Page 10 Version 0 July,2014 Beaver Drilling ProcedureCreek#24 Rev 0 Hilcorp Energy Company 9.0 R/U and Preparatory Work 9.1 Set 16" conductor at 80' below ground level. 9.2 Dig out and set impermeable cellar. 9.3 Install Seaboard slip-on 16-3/4" 3M"A" section. Ensure to orient wellhead so that tree will line up with flowline later. 9.4 Level pad and ensure enough room for layout of rig footprint and R/U. 9.5 Layout Herculite on pad to extend beyond footprint of rig. 9.6 R/U Saxon Rig# 169, spot service company shacks, spot& R/U company man&toolpusher offices. 9.7 Mud loggers not required on surface hole section. 9.8 After rig equipment has been spotted,R/U handi-berm containment system around footprint of rig. 9.9 Mix mud for 12-1/4"hole section. 9.10 Set test plug in wellhead prior to N/U diverter to ensure nothing can fall into the wellbore if it is accidentally dropped. 9.11 Install 5-1/2"liners in mud pumps. • TSM 1000 mud pumps are rated at 3633 psi (85%)/333 gpm(100%) with 5-1/2" liners. Page 11 Version 0 July, 2014 B Drillingeaver ProcedureCreek#24 Rev 0 Hilcorp Energy Company 10.0 N/U 21-1/4" 2M Diverter 10.1 N/U 21-1/4"Hydril MSP 2M diverter System. • N/U 16-3/4" 3M x 21-1/4" 2M DSA(Hilcorp)on 16-3/4" 3M wellhead. • N/U 21-1/4"diverter"T". • Knife gate, 16" diverter line. • Ensure diverter R/U complies with AOGCC reg 20.AAC.25.035(C). 10.2 Function test diverter. Ensure that the knife gate and annular are operated on the same circuit so that knife gate opens prior to annular closure. 10.3 Ensure to set up a clearly marked"warning zone" is established on each side and ahead of the vent line tip. "Warning Zone"must include: • A prohibition on vehicle parking • A prohibition on ignition sources or running equipment • A prohibition on staged equipment or materials • Restriction of traffic to essential foot or vehicle traffic only. 10.4 Set 15.375" ID wearbushing in wellhead. Page 12 Version 0 July, 2014 Beaver #2 11 Drilling Procedure Rev 0 Hilcorp Energy CompanY 10.5 Rig and Diverter Line Orientation on Beaver Creek 3 pad: F " ',...ilthr„''t C ::::r!iiiiril/it,- A' . ' ,:'4111411*„ 'kr' '''' -. iit e ,, , __,,,.. Ii -' z, ,,, - - , ir f . a sly Beaver Creek Unit Pad 3 -, = „'eel �it k Fre: July, 2014 Page 13 Version 0 Bea2 1111 Drillingver ProcedureCreek# 4 Rev 0 Hilcorp Energy Company 10.6 Diverter Schematic . 11 III I11 11 111. 111 III III • Annular Preventer . ' P . / 21-'r4"2M III III Ill III II Knife Gate ii Ili UMW 11-1 a 16' Diverter line Diverter Tee,21-%"x 21-Y4"x 2M w/16"ANSI 150 outlet ill 1I1 1!1 al lil 16-W 3M x 21 <" 2M DSA �lia li _it lir_ laill II! ? IY,Seaboard 16- -3M Casing head Assy 16" Page 14 Version 0 July, 2014 B Drillingeaver ProcedureCreek#24 Rev 0 Hilcorp Energy Company 11.0 Drill 12-1/4" Hole Section 11.1 P/U 12-1/4" directional drilling assy: • Ensure BHA components have been inspected previously. • Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. • Ensure TF offset is measured accurately and entered correctly into the MWD software. • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. • Workstring will be 4.5" 16.6# S-135 CDS40 11.2 12-1/4"BHA(GR and Res LWD are included in below BHA): Page 15 Version 0 July,2014 Beaver Creek#24 ii I- Drilling Procedure Rev 0 Hilcorp Energy Company COMPONENT DATA Item OD ID Gauge Weight Top Length Cumulatheak. Description Serial Number N (in} (in) tin) (Ibpf) Connection (ft) Length 111 HOBS-OHCTGRCMil!tooth 12.200 3.000 12250 374.30 P6-58'REG 1.20 1.20 © 8"SperryDrill Lobe 415-5.3 stg 8.000 5.000 121.08 B 6-5.18'REG 28.99 30.19 _ Stabilizer 11.500 _--- © Integral Blade Stabilizer 8.000 2.813 12.125 150.12 B 6-5r8-REG 6.00 36.19 © 8"DM Collar(Directional) 8.000 3.500 147.40 B 6-5,8'REG 9.20 45.39 © B-DGR Collar (Gamma) / 8.000 1.920 142.70 B 6-58-REG 4.55 4994 ® 8'EWR-P4 Collar(Resistrvety) / - 8.000 2.000 151.00 B 6-518'REG 12.19 62.13 ® 8"HCIM Collar{Processor) 8.000 1.920 _ 149.90 B 6-518'REG 4.97 67.10 87M-HOC(Pulser) 8.150 4.000 145.20 ®® © Orienting Sub UBHO 8000 3000 _ 147.22 B 6-518-REG ®® ® Non Mag Flex Drill Collar 8000 3.000 147.22 B 6-518'REG 30.00 IIMIM Ill Non Meg Flex Drill Collar 8000 3.000 147.22 B 6-518"REG 30.00 146 37 ® X-O 6-518 Reg Pin X 4-112"IF Box 8000 2.813 150 12 B 4-112'IF 3.50 149.87 ® 8 Joints 5'HWDP 5000 3.000 4.3C 240.00 389.87 Ell Weatherford 6-1i4"Hyd Jar 6.250 2.250 91.01 B 4-1,2''F 30.00 419.87 ® 19 Joints 5"HWDP 5.000 3.000 49.30 570.00 989.87 989.87 Bit Number Nozzles : ....12 3x'0 Bit Size (in) : 12.250 TFA (in21 : 0.8560 Manufacturer : HOBS Dull Grade In . Model Dull Grade Out .• Serial Number .• MOTOR DATA Motor Number : 2 Bend (deg) : 1.15 OD (in) : 8.000 Nozzles (32nd) : 0.0 Manufacturer : Sperry Drilling Avg Diff Press . Model : SperryDrill Cumul Cir Hrs . Serial Number . Page 16 Version 0 July, 2014 Beaver 11 Drilling ProcedureCreek#24 Rev 0 Hilcorp Energy Company 11.3 Primary Bit: 12- 1/4" (311MM) QHC1 GRC PRODUCT SPECIFICATIONS I.4DC Code 117W iE Total Tooth Count 67 Gage Row Tooth Count 39 Journal Angle 33' Offset(1'16") 6 Jet Nozzle Types Standard 83244 Extended 302447 Center Jet (If Center Jetted)501813 T.J.Connection 6-5/8"(API Reg.) Recommended Make-Up Torque* 2800032000 Ft*lbs. Bit Weight(Boxed) 250 Lbs.(1 13 Kg.) Bit Breaker (Mat.#tLegacv#) 5153531506463 ", H PRODUCT FEATURES . New patented Diamondr"4 Claw tooth bit design. ate+++ ▪ Tungsten carbide'surf inserts in gage teeth for added gage , protection. ▪ Newly formulated,proprietary hardfacing on cutting structure and tj gage maximizes carbide and diamond volume for ultimate wear a " resistance. • High-speed bearing designed for high rpm and high-energy applications. . Innovative mechanical pressure compensating system provides reliable pressure equalization and relief for maximum bearing and seal life. • Raised tungsten carbide inserts and proprietary hardfacing provides maximum arm protection in abrasive and directional applications while minimizing drill string torque. . QuadPacki Plus Series incorporates its successful"longevity" features and patented engineered hydraulics system for optimal cleaning efficiency. . Center jet feature to prevent bit balling problems Material#622394 'Calculations based on recommendations from API and tool joint manufacturers. t 2012 Halliburton.All rights reserved.Sales of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale. Page 17 Version 0 July, 2014 Beaver ProcedureCreek # 4 Rev 0 Hilcorp Energy Company 11.4 4-1/2" Workstring& HWDP will come from Saxon. Jars will come from Weatherford. 11.5 Begin drilling out from 16"conductor at reduced flow rates to avoid broaching the conductor. 11.6 Drill 12-1/4"hole section to 3,500' MD/3,216 TVD. Confirm this setting depth with the geologist and Drilling Engineer while drilling the well. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Pump at 500 - 550 gpm. Ensure shaker screens are set up to handle this flowrate. • Utilize Inlet experience to drill through coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team. • Keep swab and surge pressures low when tripping. • Make wiper trips every 500' or every couple days unless hole conditions dictate otherwise. • Ensure shale shakers are functioning properly. Check for holes in screens on connections. • Adjust MW as necessary to maintain hole stability. • TD the hole section in a good shale between 3400' MD and 3600' MD. • Take MWD surveys every stand drilled (60' intervals). 11.7 12-1/4"hole mud program summary: Weighting material to be used for the hole section will be barite. Additional barite will be on location to weight up the active system(1)ppg above highest anticipated MW. We will start with a simple gel +FW spud mud at 8.8 ppg. Pason PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. System Type: 8.8-9.5 ppg Pre-Hydrated Aquagel/freshwater spud mud Properties: Depths Density Viscosity Plastic Viscosity Yield Point API FL pH 80-3500' 8.8-9.5 ' 85-150 20-40 25 -45 <10 8.5-9.0 Page 18 Version 0 July,2014 B 111 Drileaverling ProcedureCreek #24 Rev 0 Hilcorp 1ncrgy Company System Formulation: Aquagel + FW spud mud Product Concentration Fresh Water 0.905 bbl soda Ash 0.5 ppb AQUAGEL 12-15 ppb caustic soda 0.1 ppb (9 pH) BARAZAN D+ as needed BAROID 41 as required for weight PAC-L/DEXTRID LT if required for<12 FL ALDACIDE G 0.1 ppb X-TEND II 0.02 ppb 11.8 At TD; pump sweeps, CBU, and pull a wiper trip back to the 16"conductor shoe. 11.9 TOH with the drilling assy, handle BHA as appropriate. 11.10 No open hole logs are planned for the 12-1/4"hole section. Page 19 Version 0 July, 2014 Bea #2 Drillingver Procedure 4 Rev 0 Hilcorp I:incrgy Company 12.0 Run 9-5/8" Surface Casing 12.1 R/U and pull 15.375"wearbushing. 12.2 R/U Weatherford 9-5/8" casing running equipment. • Ensure 9-5/8" BTC x CDS 40 XO on rig floor and M/U to FOSV. • R/U fill-up line to fill casing while running. • Ensure all casing has been drifted on the location prior to running. • Be sure to count the total # of joints on the location before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/vendor&model info. 12.3 P/U shoe joint,visually verify no debris inside joint. 12.4 Continue M/U &thread locking shoe track assy consisting of: • (1) Shoe joint w/float shoe bucked on(thread locked). • (1)Joint with coupling thread locked. • (1)Joint with float collar bucked on pin end&thread locked. • Install (2) centralizers on shoe joint over a stop collar. 10' from each end. • Install (1) centralizer, mid tube on thread locked joint and on FC joint. • Ensure proper operation of float equipment. 12.5 Continue running 9-5/8" surface casing • Fill casing while running using fill up line on rig floor. • Use"API Modified"thread compound. Dope pin end only w/paint brush. • M/U connections to the base of the triangle stamped on the pin end. Note M/U torque values required to achieve this position. Estimated torque to reach base of triangle: 10,750 ft-lbs. • After making up several connections, use the torque required to M/U to base of triangle as the M/U torque and continue running string. • Install (1) centralizer every other joint to 300'. Do not run any centralizers above 300' in the event a top out job is needed. • Utilize a collar clamp until weight is sufficient to keep slips set properly. 9-5/8" BTC Estimated M/U Torque Casing OD Est Torque to Reach Triangle Base 9-5/8" 9,630 ft-lbs Page 20 Version 0 July, 2014 Beaver PCreekrocedure# 4 Rev 0 Hilcorp Energy Company Tenaris Casing and Tubing Performance Data Choose pipe size,wall thickness and steel grade to view API connection options and performance data. Size 111111111111 Wall 1113 Grade-0 Connection 0 Unit Pipe Body Data GEOMETRY El Nominal OD 9.625 in Wall Thickness 0.395 in API Drift Diameter 8.679 in Nominal Weight 40.00 lbs./ft Nominal ID 8.835 in Alternate Drift Diameter 8.75 in Plain End Weight 38.97 lbslft Nominal Cross Section 11.454 sq in PERFORMANCE Steel Grade L80 Minimum Yield 80,000 psi Minimum Ultimate 95,000 psi Body Yield Strength 916,000 lbs Internal Yield Pressure 5,750 psi Collapse Pressure 3,080 psi HI 1 I► Connection Data GEOMETRY Regular OD 10.625 in Threads Per Inch 5 Make-Up Thread Turns 1 PERFORMANCE Steel Grade L80 Minimum Yield 80,000 psi Minimum Ultimate 95,000 psi Joint Strength 947,000 lbs Internal Pressure 5,750 psi Resistance TenarisHydril Premium Connections Print Contact Us Ver 8.6 12.6 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 12.7 Slow in and out of slips. 12.8 P/U casing hanger joint and M/U to string. Casing hanger joint will come out to the rig with the landing joint already M/U. Position the shoe as close to TD as possible. Strap the landing joint while it is on the deck and mark the joint at (1) ft intervals to use as a reference when landing the hanger. 12.9 Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. Page 21 Version 0 July, 2014 Beaver II Drilling ProcedureCreek#24 Rev 0 Hilcorp Emu Company 12.10 R/U circulating equipment and circulate the greater of 1 x casing capacity or 1 x OH volume. Elevate the hanger offseat to avoid plugging the flutes. Stage up pump slowly and monitor losses closely while circulating. 12.11 After circulating, lower string and land hanger in wellhead again. Page 22 Version 0 July, 2014 1 BDe111 r PCreekrocedure# 4 Rev 0 Hilcorp Energy Company 13.0 Cement 9-5/8" Surface Casing 13.1 Hold a pre job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud& water can be delivered to the cmt unit at acceptable rates. • How to handle cmt returns at surface. • Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. • Positions and expectations of personnel involved with the cmt operation. 13.2 Document efficiency of all possible displacement pumps prior to cement job 13.3 R/U cmt head (if not already done so). Ensure top and bottom plugs have been loaded correctly. 13.4 Pump 5 bbls 10 ppg spacer. Test surface cmt lines. 13.5 Pump remaining 30 bbls of 10 ppg spacer. 13.6 Drop bottom plug. Mix and pump cmt per below recipe. 13.7 Cement volume based on annular volume + 50% open hole excess. Job will consist of lead & tail, TOC brought to surface. Estimated Total Cement Volume: Section: Calculation: Vol(BBLS) Vol(ft3) 12.0 ppg LEAD: 80' x .129 bpf= 10.3 57.8 16" Conductor x 9-5/8" casing annulus: 12.0 ppg LEAD: (3000' — 80') x .0558 bpf x 1.5 = 244.4 1372 12-1/4" OH x 9-5/8" Casing annulus: Total LEAD: 254.7 bbl 1429.8 ft3 TAIL: (3500'-3000') x .0558 bpf x 1.5 = 41.9 235.3 12-1/4" OH x 9-5/8" Casing annulus: TAIL: 90 x .096 bpf = 8.7 48.8 9-5/8" Shoe track: Total TAIL: 50.6 bbl 284.1 ft3 Page 23 Version 0 July, 2014 B Drillingeaver ProcedureCreek#24 Rev 0 Hilcorp Energy Company Cement Slurry Design: Lead Slurry (3000' MD to surface) Tail Slurry (3500' to 3000' MD) System Extended Conventional Density 12 lb/gal 15.4 lb/gal Yield 2.46 ft3/sk 1.22 ft3/sk Mixed Water 14.349 gal/sk 5.507 gal/sk Mixed Fluid 14.469 gal/sk 5.507 gal/sk Code Description Concentration Code Description Concentration G Cement 94#/sk A Cement 94#/sk Additives D110 Retarder 0.15 gal/sk BWOC D046 Anti Foam 0.2% BWOC D046 Anti Foam 0.2% BWOC D065 Dispersant 0.4% BWOC D079 Extender 2.0% BWOC S002 CaCl2 0.35% BWOC D020 Extender 3.0% BWOC D177 CaCl2 0.1% BWOC i 13.8 Attempt to reciprocate casing during cement pumping if hole conditions allow. Keep the hanger elevated above the wellhead while working. If the hole gets "sticky", land the hanger on seat and continue with the cement job. 13.9 After pumping cement, drop top plug and displace cement with 9.0 ppg 6% KCL PHPA. 13.10 Ensure cement unit is used to displace cmt so that volume tracking is more accurate. 13.11 Displacement calculation: 3500'- 80' = 3420' x .0758 bpf=259.2 bbls 13.12 Monitor returns closely while displacing cement. Adjust pump rate if necessary. If hanger flutes become plugged, open wellhead side outlet in cellar and take returns to cellar. Be prepared to pump out fluid from cellar. Have some sx of sugar available to retard setting of cement. Page 24 Version 0 July, 2014 Beaver Drilling ProcedureCreek#24 Rev 0 Hilcorp 13.13 Do not overdisplace by more than V2 shoe track volume. Total volume in shoe track is 8.7 bbls. • Be prepared for cement returns to surface. If cmt returns are not observed to surface, be prepared to run a temp log between 12— 18 hours after CIP. • Be prepared with small OD top out tubing in the event a top out job is required. The AOGCC will require us to run steel pipe through the hanger flutes. The ID of the flutes is 1.5". 13.14 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold, pressure up string to final circulating pressure and hold until cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating pressure if pressure must be held. 13.15 R/D cement equipment. Flush out wellhead with FW. 13.16 Back out and L/D landing joint. Flush out wellhead with FW. 13.17 M/U pack-off running tool and pack-off to bottom of Landing joint. Set casing hanger packoff. Run in lock downs and inject plastic packing element. 13.18 Lay down landing joint and pack-off running tool. Ensure to report the following on wellez: • Pre flush type, volume(bbls)&weight(ppg) • Cement slurry type, lead or tail,volume&weight • Pump rate while mixing,bpm, note any shutdown during mixing operations with a duration a. Pump rate while displacing,note whether displacement by pump truck or mud pumps,weight&type of displacing fluid b. Note if casing is reciprocated or rotated during the job c. Calculated volume of displacement, actual displacement volume,whether plug bumped&bump pressure, do floats hold d. Percent mud returns during job, if intermittent note timing during pumping of job.Final circulating pressure e. Note if pre flush or cement returns at surface&volume f. Note time cement in place g. Note calculated top of cement h. Add any comments which would describe the success or problems during the cement job Send final "As-Run"casing tally & casing and cement report to mmyers@hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. Page 25 Version 0 July, 2014 Beaver Drilling ProcedureCreek #24 Rev 0 Hilcorp Energy Company 14.0 BOP N/U and Test 14.1 N/D the diverter. 14.2 N/U Seaboard multi-bowl wellhead assy. Install 9-5/8"packoff P-seals. Test to 3000 psi. 14.3 N/U 11"x 5M T3-Energy BOP as follows: • BOP configuration from Top down: 11"x 5M T3-Energy annular BOP/11"x 5M T3-Energy Model 6011i double ram/11"x 5M mud cross/11"x 5M T3-Energy Model 6011i single ram • Double ram should be dressed with 2-7/8 x 5" VBRs in top cavity, blind ram in btm cavity. • Single ram should be dressed with 2-7/8 x 5" VBRs • N/U bell nipple, install flowline. • Install (2) manual valves &a check valve on kill side of mud cross. • Install (1) manual valve on choke side of mud cross. Install an HCR outside of the manual valve. 14.4 Run 4-1/2"BOP test assy, land out test plug (if not installed previously). • Test BOP to 250/4000 psi for 10/10 min. Test annular to 250/2500 psi for 10/10 min. • Ensure to leave "B" section side outlet valves open during BOP testing so pressure does not build up beneath the test plug. 14.5 R/D BOP test assy. 14.6 Dump and clean mud pits, send spud mud to G&I pad for injection. 14.7 Mix 9.0 ppg 6% KCL PHPA mud system. 14.8 R/U mud loggers for production hole section. 14.9 Set 10" ID wearbushing in wellhead. 14.10 Rack back as much 4-1/2" DP in derrick as possible to be used while drilling the hole section. Page 26 Version 0 July, 2014 Beaver ling ProcedureCreek#24 Rev 0 Hilcorp Energy Company 15.0 Drill 8-1/2" Hole Section 15.1 P/U 8-1/2" directional BHA. 15.2 Ensure BHA components have been inspected previously. 15.3 Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. 15.4 TF offset is measured accurately and entered correctly into the MWD software. 15.5 Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. 15.6 Workstring will be 4.5" 16.6# S-135 CDS40. Page 27 Version 0 July, 2014 II Beaver Creek#24 Drilling Procedure Rev 0 Hilcorp Energy Company 15.7 8-1/2" BHA: OMPONENT DATA OD ID Gauge Weight Top Length Cumulative "ber in in Ceneusdfon ( ) { ) fin) (140, (ft) Length (ft) 1 HOBS-FX65D PDC 8.400 2.500 8.500 172.13 P 4-112"REG 1.00 1.00 2 7"SperryDrill Lobe 7.8-6.0 stg 7.000 4.952 93.13 B 4-1+2'IF 27.38 28.38 Stabilizer 7.750 3 Non Mag Float Sub 6.750 2.75C 101.71 8 4-12"IF 3.0C 31.38 4 Integral Blade Stabilizer(NM) 6.750 2.813 8.375 100.77 B 4-112"IF 5.0C 36.38 5 6 314"DM(Directional) 8.750 3.125 103 40 B 4-112"IF 9.20 45.58 6 6 3./4"BAT (Sonic) 6.750 1.905 97.70 B 4-112"IF 29.30 65.89 7 6 314"DGR(Gamma) 6.750 1.920 97.80 B 4-112"IF 4.55. 70 44 8 6 314"EWR-P4 (Resistively) , 6.750 2.000 104.30 B 4-112"IF 12.10 82.54 9 6 3.4'HCIM (Processor) 6.750 1.920 101.70 B 4-112'IF 4.97 87.51 10 6 3,+4"ALD (Density) / 6.750 1.920 8.250 104.30 B 4-112"IF 14.54 102.05 Stabilizer 8.250 11 6 314'CTN(Neutron} 6.750 1.905 132 30 B 4-12"IF 11.84 113 89 12 6 3l4"TM-HOC(Pulser) 6.900 3.250 19360 B 4.112'IF 15.59 129.48 13 Non Mao Flex Drill Collar 6.750 2.813 100 77 8 4-112"IF 30.00 159.48 14 Non Mag Flex Drill Collar 6.750 2.813 130 77 B 4-112"IF 30.00 18948 15 8 Joints 5'HWDP 5.000 3.000 49.30 240.00 429.48 16 Weatherford 6-114"Jars 6.250 2.250 91.01 B 4-112'IF 30.00 459.48 17 19 Joints 5"HWDP 5.000 3.000 49.30 570.00 1029.48 111111111111_12_329 BIT DATA 406- , Bit Number - Nozzles :5x13 Bit Size (in) : 8 500 TFA (in2) : 0.6461 ManufacturerDull Grade In • Model Dull Grade Out Serial Number .• MOTOR DATA Motor Number : 1 Bend (deg) : 0.00 00 (in) : 7.000 Nozzles (32nd) : 0.0 Manufacturer : Sperry Drilling Avg Diff Press .• Model : SperryDrill Cumul Cir Hrs .• Serial Number . Page 28 Version 0 July, 2014 B #2 Drillingeaver Procedure Rev 0 Hilcorp Energy Company 15.8 Primary Bit: HALLIEIURTON 8-1/2" (216mm) FX55 PRODUCT SPECIFICATIONS Culler Type X.3-Extreme Ckill +• !.ADC Code 54424 Body Type MATRIX Total Cutter Count 41 '," Cutter Distriluunts Face O 26 w Gouge 5 S Up Drill 5 Ct Number of Laree Nozzles c Number of Medium Nonks 0 Number of Small Nozzles 0 Number of Micro Nonles 0 §' Number of Pons 0 Junk Sloe Area lsgint 1176 o Nomulirod Face Volturse 3706 API Connection 4-1:2 REG.PLN Recommended Makc-[:p Teague' 12.461 17,766Ft•lbs- �+�+ woof Nominal t)unenssons•• ineeo Make-Cp Face to Nose 11.11.in-2R2 ram Ciaupe Length 2 it-51 hada Sleeve Lerepth Orn-Dram Shank Diameter 6 in-152 num Break Oral Pane at.k•Legacy I 181954^!411410 Approsiniate Slurping Wants' ISOLbs.-�ila[Cg SPECIAL FEATURES I p-pki11 Cutters on Gage Pinks.1:12..RetieNkd Gage Miaicrial 6657916 •Rid specific tecommenkil rmi,e-ur ng-ie is a fmc:iifn of the hit UI and aciml bit sdr 01.11 utilized as specified am API RP7O Section A.8.1 ••lkstm dxronsinrts ue nominal and nett smy slightly en monthctured peoduet 11x15-lantcve ME Bits and Services models are continuously usly m hoed and refused Ptedo:t Tenf-srions ma}change without nonce. 2012 H.tllibun n.All nphts reserved_Sales of Halliburton prcdtw-ts and services will be in accord solely with the terms and conditions contained in the contract between Elalttihiarton and the customer that is applicable to the sale. www.halliburton.com Page 29 Version 0 July, 2014 Bea #2 Drillingver Procedure Rev 0 Hilcorp Energy Company 15.9 8-1/2"hole section mud program summary: Weighting material to be used for the hole section will be salt and calcium carbonate. Additional calcium carbonate will be on location to weight up the active system(1)ppg above highest anticipated MW. 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: 9.0 ppg 6%KCL PHPA fresh water based drilling fluid. Properties: Mud Plastic MD Weight Viscosity Viscosity Yield Point pH HPHT 3500'-9,675' 9.0— 10.0 . 40-53 15-25 15-25 8.5-9.5 < 11.0 System Formulation: 6% KCL EZ Mud DP Product Concentration Water 0.905 bbl KCl 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 15-20 ppb(5 ppb of each) BAROID 41 as required for a 9.0—10.5 ppg ALDACIDE G 0.1 ppb BARACOR 700 1 ppb BARASCAV D 0.5 ppb (maintain per dilution rate) 15.10 TIH w/8-1/2" directional assy to TOC. Shallow test MWD and LWD on trip in. Note depth TOC tagged on AM report. 15.11 R/U and test casing to 3000 psi/30 min. Ensure to record volume/pressure and plot on FIT graph. AOGCC reg is 50% of burst. 15.12 Drill out shoe track and 20' of new formation. 15.13 CBU and condition mud for FIT. Page 30 Version 0 Jul 2014 Y� Beaver PCreekrocedure# 4 Rev 0 Hilcorp Emmy Company 15.14 Conduct FIT to 11 ppg EMW. Note: Offset field test data predicts frac gradient at the 9-5/8"shoe to be btwn 15 - 16 ppg EMW. An 11 ppg FIT results in a 2 ppg kick margin while drilling with the planned MW of 9 pp& 15.15 Drill 8-1/2"hole section to 9,675' MD/ 9,080 TVD • BHL is 1570' West from Unit boundary, DO NOT OVERSHOOT BH TARGET! ✓ • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Pump at 400 - 500 gpm. Ensure shaker screens are set up to handle this flowrate. • Utilize inlet experience to drill through coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team,try to avoid sliding through coal seams. Work through coal seams once drilled. • Keep swab and surge pressures low when tripping. • Make wiper trips every 500' or every couple days unless hole conditions dictate otherwise. • Ensure shale shakers are functioning properly. Check for holes in screens on connections. • Adjust MW as necessary to maintain hole stability. Keep HTHP fluid loss < 10. • Take MWD surveys every other stand drld. Surveys can be taken more frequently if deemed necessary. • Take (3) sets of formation samples every 20'. Mud loggers should compile Pixler plots and QFT 2 analysis for Lower Tyonek to total depth. 15.16 At TD; pump sweeps, CBU, and pull a wiper trip back to the 9-5/8" shoe. 15.17 TOH with the drilling assy, laying down drill pipe and BHA. 15.18 Install 5-1/2"pipe rams in BOP stack and RU and test. Page 31 Version 0 July, 2014 Bea Drillingver ProcedureCreek #24 Rev 0 Hilcorp Energy Company 16.0 Run 5-1/2" Production Casing 16.1. R/U Weatherford 5-1/2" casing running equipment. • Ensure 5-1/2" DWC/C HT x 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 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. 16.2. P/U shoe joint, visually verify no debris inside joint. 16.3. Continue M/U&thread locking shoe track assy consisting of: • (1) Shoe joint w/ shoe bucked on&threadlocked (coupling also thread locked). • (1)Joint with float collar bucked on pin end&threadlocked (coupling also thread locked). • Solid body centralizers will be pre-installed on shoe joint an FC joint. • Leave centralizers free floating so that they can slide up and down the joint. • Ensure proper operation of float shoe and float collar. • Utilize a collar clamp until weight is sufficient to keep slips set properly 16.4. Continue running 5-1/2" 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 joint across zones of interest, TBD after LWD. • Install solid body centralizers on every other joint to 9-5/8" shoe. Leave the centralizers free floating. • Pick up swell packer and place in string at approximately 3000'. 16.5. Continue running 5-1/2"production casing 5-1/2" DWC/C HT M/U torques Casing OD Minimum Maximum Yield Torque 5.5" 12,000 ft-lbs 13,800 ft-lbs 18,700 ft-lbs Page 32 Version 0 July, 2014 B Drillingeaver ProcedureCreek#24 Rev 0 Hilcorp Energy Company Technical Specifications Connection Type: Size(O.D.): Weight (Wall): Grade: DWC.0-HT Casing 5-112 in 17.00 Ibrft (0.304 in) P-110 standard Material P-110 Grade 110,000 Minimum Yield Strength (psi) INNIN U SA 125,000 Minimum Ultimate Strength (psi) VAM USA 4424 W.Sam Houston Pkwy.Sole 150 Pipe Dimensions Houston.TX 77041 Phone:713-479-3200 5.500 Nominal Pipe BodyO.D. (in) Fax:713-479-3234 4.892 Nominal Pipe Body I.D.(in) E-mail:VAMUSAsates(¢wam-usa.com 0.304 Nominal Wall Thickness(in) 17.00 Nominal Weight (Ibsrft) 16.89 Plain End Weight(lbs/ft) 4.962 Nominal Pipe Body Area (sq in) Pipe Body Performance Properties 546,000 Minimum Pipe Body Yield Strength (lbs) 7,480 Minimum Collapse Pressure (psi) 10,640 Minimum Internal Yield Pressure (psi) 9,700 Hydrostatic Test Pressure (psi) Connection Dimensions 6.050 Connection O.D. (in) 4.892 Connection I.D. (in) 4.767 Connection Drift Diameter(in) 4.13 Make-up Loss (in) 4.962 Critical Area (sq in) 100.0 Joint Efficiency(%) Connection Performance Properties 546.000 Joint Strength (lbs) 22,940 Reference String Length (ft) 1.4 Design Factor 568,000 API Joint Strength (lbs) 546,000 Compression Rating (lbs) 7,480 API Collapse Pressure Rating (psi) 10.640 API Internal Pressure Resistance (psi) 91.7 Maximum Uniaxial Bend Rating [degrees1100 ft] Appoximated Field End Torque Values 12.000 Minimum Final Torque (ft-lbs) 13,800 Maximum Final Torque(ft-lbs) 18,700 Connection Yield Torque(ft-lbs) For detailed information on performance properties.refer to DWC Connection Data Notes on following page(s). Page 33 Version 0 July, 2014 Bea #2 II Drillingver Procedure Rev 0 Hilcorp Enemy Company 16.6. Run in hole w/5-1/2" casing to the 9-5/8" casing shoe. 16.7. Fill the casing with fill up line and break circulation every 1,500 feet to the window or as the hole dictates. 16.8. Obtain slack off weight, PU weight, rotating weight and torque of the casing. 16.9. Circulate 2X bottoms up at shoe, ease casing thru shoe. 16.10. Continue to RIH w/casing no faster than 1 jt./minute. Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 16.11. Set casing slowly in and out of slips. 16.12. PU 5-1/2"X 8-1/2" swell packer to be placed at approximately 3000'. Swell packer should have 10' handling pups installed on both ends with bow spring centralizers on pups. 16.13. Swedge up and wash last 2 joints to bottom. P/U 5' off bottom. Note slack-off and pick-up weights. 16.14. Stage pump rates up slowly to circulating rate. Circ and condition mud with casing on bottom. Circulate 2X bottoms up or until pressures stabilize and mud properties are correct and the shakers are clean. Reduce the low end rheology of the drilling fluid by adding water and thinners. 16.15. Reciprocate string if hole conditions allow. Circ until hole and mud is in good condition for cementing. Page 34 Version 0 July,2014 Beaver #24 111 Drilling Procedure Rev 0 Hilcorp Energy co, 17.0 Cement 5-1/2" Production Casing 17.1. Hold a pre job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud & water can be delivered to the cmt unit at acceptable rates. • How to handle cmt returns at surface, regardless of how unlikely it is that this should occur. • Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. • Positions and expectations of personnel involved with the cmt operation. • Document efficiency of all possible displacement pumps prior to cement job. 17.2. Attempt to reciprocate the casing during cmt operations until hole gets sticky 17.3. Pump 5 bbls of 12.5 ppg Mud Push spacer. 17.4. Test surface cmt lines to 4500 psi. 17.5. Pump remaining 30 bbls 10.5 ppg Mud Push spacer. 17.6. Mix and pump lead and tail cement per below recipe. Ensure cement is pumped at designed weight. Job is designed to pump 35% OH excess. Section: Calculation: BLS) Vol (ft3) (B9-5/8"x 5-1/2" Csg Overlap: 500' x 0.0464 = 23.2 130.4 8-1/2" OH x 5-1/2" Casing: (9675 — 3500) x 0.0408 x 1.35 = 340.1 1909.5 Shoe Track: 80' x 0.02325 = 1.9 10.4 Total Volume : 365.2 2050.4 Page 35 Version 0 July, 2014 B II Drillingeaver PCreekrocedure#24 Rev 0 Hilcorp Energy Company EASYBLOK (9675' to 3000') System Conventional Density 15.3 lb/gal Yield 1.36 ft3/sk Mixed Water 5.93 gal/sk Mixed Fluid 5.93 gal/sk Code Description Concentration Class G Cement 94#/sk D046 Foam Preventer 0.2% BWOC D202 Dispersant 1.5% BWOC Additives D400 EASYBLOK 0.8% BWOC D154 Extender 8.0% BWOC D174 Expanding Additive 1.5% BWOC D198 Retarder 0.3% BWOC 17.7. Drop wiper plug and displace with produced water. 17.8. If hole conditions allow—continue reciprocating casing throughout displacement. This will ensure a high quality cement job with 100% coverage around the pipe. 17.9. If elevated displacement pressures are encountered, position casing at setting depth and cease reciprocation. Monitor returns &pressure closely while circulating. Notify Drilling Foreman immediately of any changes. 17.10. Bump the plug and pressure up to 500 psi over final lift pressure. Hold pressure for 3 minutes. 17.11. Do not overdisplace by more than 1/2 shoe track. Shoe track volume is 1.9 bbls. Page 36 Version 0 July, 2014 Bea #2 Drillingver Procedure Rev 0 Hilcorp Energy Company 17.12. Bleed pressure to zero to check float equipment. Watch for flow. Note amount of fluid returned after bumping plug and releasing pressure. 17.13. RD cementers and flush equipment. 17.14. WOC minimum of 12 hours,test casing to 3000 psi and chart for 30 minutes. Ensure to report the following on wellez: • Pre flush type,volume(bbls)&weight(ppg) • Cement slurry type, lead or tail,volume&weight • Pump rate while mixing,bpm,note any shutdown during mixing operations with a duration i. Pump rate while displacing,note whether displacement by pump truck or mud pumps,weight&type of displacing fluid j. Note if casing is reciprocated or rotated during the job k. Calculated volume of displacement, actual displacement volume,whether plug bumped&bump pressure, do floats hold 1. Percent mud returns during job, if intermittent note timing during pumping of job.Final circulating pressure m. Note if pre flush or cement returns at surface&volume n. Note time cement in place o. Note calculated top of cement p. Add any comments which would describe the success or problems during the cement job Send final "As-Run"casing tally & casing and cement report to mmyers@hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. Page 37 Version 0 July, 2014 Bea II Drillingver ProcedureCreek#24 Rev 0 Hilcorp Enemy Company 18.0 RDMO 18.1. Install BPV in wellhead 18.2. N/D BOPE 18.3. N/U temp abandonment cap 18.4. RDMO Saxon Rig#169 c 6 L 4.. 79-7'1 IT-IA r 7 +-..)1, Page 38 Version 0 July, 2014 Beaver ProcedureCreek# 4 Rev 0 Hilcorp Energy Company 19.0 BOP Schematic 3.5" Model 6011i ii"5ooi! rflatift ort3.OJ' .... rl .. T 3 inerlag MOE VOA I tti10del;r81gy : .r- 11i Ill tll 111 2.110' lip lit: : 4 t IE1 III w.f.w.f. • �' I#1 2 1/16 SM Kill Side 1/8 5M Choke Side . � T-3=ner: ;r 1;11' 111 iudel7C?8Z [ ...., qtr- 11."-501X1 ;;; III 11I I6I lir IEI Grade Ii$ III 111111 Iii • �rmot 1.0 ' 5/8•: Page 39 Version 0 July, 2014 Beaver Creek#24 Drilling Procedure Rev 0 Hilcorp Energy Company 20.0 Wellhead Schematic Beaver Creek New Drill-Saxon 169 16 X95/8 X51/2 Tree cap,Otis,5 1/8 5M FE X 9'A Otis Quick Union 1111 1.1.11111.110. Valve,Swab,WKM-M, 51/8 FE,HWO, DD ®� DD trim •t� • •,. Valve,Wing,WKM-M, ' u = ;4111.,"16. 3 i/8 SM FE,HWO, fit; 'rValve, WKM-M Wing, -y \}d � 31/85M FE,HWO, DD trim a A DD trim Nil or• Valve,Upper Master, WKM-M,5 1/8 5M FE,HWO, DD trim \\ CO \„/ Crossover spool, '•u•r r•n:. 5 1/8 5M FE X 5 1/8 10M FE me:n Valve,Master,CIW-FC, 1 ,, 5 1/8 10M FE,HWO, 0 EE trim U L. sai• a.II ra Tubing head,Seaboard-S8, 163/43MX11 SM, m w/2-21/165M 550 !fill�� � 411 •. 9 5/8 P seal bottom Starting head Seaboard, 16''A 3M 16 SOW BTM, jp( _ �ja'r�KOMI' w/2-2 1/16 5M SSO • 16" 9 5/8" - 5N Page 40 Version 0 July, 2014 Beaver 11 Drilling ProcedureCreek#24 Rev 0 Hilcorp Energy Company 21.0 Days Vs Depth Days Vs Depth 0 -Beaver C reek 24 2000 4000 L 2 m A V 8000 10000 12000 0 5 10 15 20 25 30 Days Page 41 Version 0 July, 2014 Beaver Creek#24 ii I- Drilling Procedure Rev 0 Hilcorp Energy Company 22.0 Geo-Prog GEOLOGICAL PROGNOSIS WELL NAME: BCU 24 (GR well from Pad 3) FIELD: Beaver Creek SURFACE X: 317464.4 STATE: Alaska SURFACE Y: 2434055.9 BHL X 319393.5 TVD REF D -CI'.,;KB BHL Y 2432155.9 TVD REF ELEV 179 18.6'KB(Saxon 169) COORD REF. SYSTEM NAD27 GROUND ELEV , 160.6 PROPOSED TD MD: 9675 PROPOSED TD TVD: 9080 Objective: Beluga B18-B32,Sterling B-1 to B-4 and Shallow gas Amplitude Geo Summary/ Justification: The well will test the Beluga B18-B32 gas sands on the west side of Beaver Creek;and test the Shallow Gas Amplitude in a structural and strategraphic position on it way to the deeper objectives ANTICIPATED FORMATION TOPS&GEOHAZARDS EXPECTED Critical intersection Point TOP TOP NAME FORMATION FLUID MD TVD(FT) Est. Pressure X Y +7- SHALLOW_GAS1 Sterling water/gas 3277 3018 1200-1300 psi 318233.3 2433233.3_ +/-15 BC_BIST Sterling water/gas 5340 4852 1900-2300 psi 318926.7 2432590.7 +/-15 BC_B4ST Sterling water/gas 5805 5265 1900-2300 psi 319082.8 2432446.4 +/-15 UBC3 Beluga water/gas 6618 • 6032 1000-3300 psi 319275.5 2432268.3 +/-25 BC B18UST Beluga Gas 7789 7196 1000-3400 psi 319362.4 2432187.6 +/-25 BC_B24ST Beluga Gas 8317 7723 3000-3500 psi 319393.6 2432158.6 +/-25 BC_B28ST Beluga Gas 8471 7877 3000-3600 psi 319394.8 2432157.5 +/-25 BC_B3OST Beluga Gas 8727 8132 3000-3600 psi 319394.8 2432157.5 +/-25 SR_TYONEK Tyonek Wet 9313 8719 3000-3600 psi 319394.8 2432157.5 +/-25 TD 9675 9080 =Primary Objective =Secondary Objective TARGET RADIUS 50 ft DATA COLLECTION REQUIREMENTS: Mud Logging: Full crew of 4 for production hole section. 2 sets of washed&dried samples collected every 20 ft from KOP to TD. Pixier plot! LWD Data: Sperry Triple Combo LWD E-Line Log Data: COMPLETION TYPE ANTICIPATED RATES ARTIFICIAL LIFT EQUIPMENT OD TUBING SIZE 2-7/8" OTHER COMMENTS 2. We do not anticipate crossing any significant faults that would pose drilling problems. 3. BCU 14&01B drilled with 9.5 ppg mud through the Sterling and 9.3-9.9 ppg mud through the lower Beluga 4. We expect similar conditions encountered in the drilling of the BCU 01B well in early 2014 Page 42 Version 0 July, 2014 Beaver Drilling ProcedureCreek#24 Rev 0 Hilcorp Enemy Company 23.0 Anticipated Drilling Hazards 12-1/4" Hole Section: Lost Circulation: Ensure 500 lbs of medium/coarse fibrous 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/ gel and gel extender. Sweep hole with gel or flowzan sweeps as necessary. Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. Maintain YP btwn 25 —45 to optimize hole cleaning and control ECD. Wellbore stability: Lithology through this zone is a composite of pebble conglomerate and sand in the upper intervals with intermittent clay matrix. Carbonaceous material and coal may be noted. Gravel sizes that are larger than normal can cause hole-cleaning problems. If encountered, be prepared to increase the viscosity. Excessive quantities of gravel and sand may indicate wellbore instability. Increase properties up to a YP of—50 -—60 lbs/100ft2 to combat this issue. Maintain low flow rates for the intial 200' of drilling to reduce the likelihood of washing out the conductor shoe. To help insure good cement to surface after running the casing, condition the mud to a YP of 25 —30 prior to cement operations. Do not lower the YP beyond 25 to avoid trouble with sands that may be found on this well. Have Desco DF, SAPP, and water on hand to ensure the desired rheologies can be achieved. H2S: H2S is not present in this hole section. No abnormal pressures or temperatures are present in this hole section. Page 43 Version 0 July, 2014 Beaver Creek#24 ii I- Drilling Procedure Rev 0 Hilcorp Enemy Company 8-1/2" Hole Section: Lost Circulation: Ensure 1000 lbs of each of the different sizes of Calcium Carbonate are available on location to mix LCM pills at moderate product concentrations. Hole Cleaning: Maintain rheology w/viscosifier as necessary. Sweep hole w/20 bbls hi-vis pills as necessary. Optimize solids control equipment to maintain density and minimize sand content. Maintain YP btwn 20 - 30 to optimize hole cleaning and control ECD. Wellbore stability: Maintain MW as necessary using additions of Calcium Carbonate as weighting material. A torque reduction lube may be used in this hole section in concentrations up to 3% if needed. Maintain 6% KCl in system for shale inhibition. Coal Drilling: The following lessons were learned from extensive experience drilling coal seams in Cook Inlet. The need for good planning and drilling practices is also emphasized as a key component for success. • Keep the drill pipe in tension to prevent a whipping effect which can disturb coal sections. • Use asphalt-type additives to further stabilize coal seams. • Increase fluid density as required to control running coals. • Emphasize good hole cleaning through hydraulics, ROP and system rheology. H2S: H2S is not present in this hole section. No abnormal temperatures are present in this hole section. Page 44 Version 0 July, 2014 Beaver Creek#24 II 1-- Drilling Procedure Rev 0 Hilcorp Energy Company 24.0 Saxon Rig 169 Layout ,,E pest__ ---- -- 1111.--_ iiilill e ig,,--ar,fM15'ism __ E E tE T Ef I I-I_IhI=I=i ILII' 111'11 tir 1�I I _ 'a4'- -s aTir�io I IIP Il <)r x -' �,� ' -rhi�ll�`� IIIA — IIIII .= n��e III�� 7=„_„,.,111 I�� Emosii r ,,) ISI. I ` if& _,� .1 1!I --A•;: ......,,.±._.:=.il II IM TQJlllll - -Ui!in i _ __ ra-...__ ..- -. _��7e_ --_�-=SI r 11 I Moe a <u �+R•N,TPo (� , , T 1,-.4--i--..74,-,„,,,,„„.„.„I __ nn� I ...- li . .._ r ),III X11 I11 II 11111 1111111 ,'I I...,.Iy, ..... I Page 45 Version 0 July,2014 B 1111 Drillingeaver ProcedureCreek#24 Rev 0 Hilcorp }?ncrgy Company 25.0 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 46 Version 0 July, 2014 Beaver Creek#24 tit F Drilling Procedure Rev 0 Hilcorp tinerpy Company 26.0 Choke Manifold Schematic u s f 11 its, ---r p ,.; G gr-,1 WEI .1 r,i'T*4,t ll il 1111110d I r) ,,,,: tivti)41di & : illi . tf 1.11.1111 .t--. a Si' in t M. -- '4i.ti. . 'i v 0 `�s7 D a N Tlli. l �� 1 -411" ... �� =r11. -.— •��+141:11 166 I,r�%r n e 6 I L— L I .. So,/... a m 7 r s 4 —m— �' .�� � dti e t ` : l+;rs w1 1:Viii 0 aim ;AIME 11111l�r I a �� I t .! y , g F` li ti 0 t L dame - mgr 1C? L+ in rlia=b1(; r.i4.14,,, ; 1 i 1 ,, il Ili ;4111111 P b 4141 — j—— �' — X ill Page 47 Version 0 July, 2014 Bea #2 11 Drillingver Procedure Rev 0 Hilcorp Energy Company 27.0 Casing Design Information Calculation &Casing Design Factors Beaver Creek Unit DATE:6/20/2014 WELL: Beaver Creek#24 FIELD: Beaver Creek DESIGN BY:Monty M Myers Design Criteria: Hole Size 12-1/4" Mud Density: 8.8 ppg Hole Size 8-1/2" Mud Density: 9.0 ppg Hole Size Mud Density: Drilling Mode MASP: 1792 psi (see attached MASP determination&calculation) MASP: Production Mode MASP: 2688 psi (see attached MASP determination&calculation) Collapse Calculation: Section Calculation 1 Normal gradient external stress (0.435 psi/ft)and the casing evacuated for the internal stress Casing Section Calculation/Specification 1 2 3 4 Casin OD 9-5/8" `• 5-1/2" ; i Top. D)......_.._ __......_..__...._.. 0 I 0 . --+---. Bottom MD 3,500 9,675 Bottom(TVD) 3,216 9,080 Length 3,500 9,675 ' Weight(ppf) 40 17 I '• Grade L-80 P-110 i Connection BTC DWC/C HTJ -' Weight w/o Bouyancy Factor(lbs) 140,000 164,4757 Tension at Top of Section.(Ibsj 140,000 164,475 I I Min strength Tension(1000 lbs)_.._.. _.._._916 _ .546_.._ _.._ 3._ _...._. ...._ _.._..____1 Worst Case Safety Factor(Tension) 6.54 3.32 1 1 Collapse Pressure at bottom (Psi) 1,399 3,950 Collapse Resistance w/o tension(Psi) 3,090 7,480 Worst Case Safety Factor(Collapse) 2.21 1.89 MASP(psi) 1,077 2,688 Minimum Yield(psi) 5,750 10,640 , Worst case safety factor(Burst) 5.34 3.96 , 1 Page 48 Version 0 July, 2014 Beaver Creek #24 Drilling Procedure Rev 0 Hilcorp Energy Company 28.0 8-1/2" Hole Section MASP Maximum Anticipated Surface Pressure Calculation 8-1/2"Hole Section Hilo Beaver Creek#24 Beaver Creek Unit MD TVD Planned Top: 0 0 Planned TD: 9675 9080 Anticipated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG Grad Shallow Gas 3016 1300 WATER/GAS 8.3 0.431 B2 5058 2300 WATER/GAS 8.7 0.455 B4 5249 2300 WATER/GAS 8.4 0.438 UBC3 6068 2850 WATER/GAS 9.0 0.470 B18 7264 3400 GAS 9.0 0.468 B24 7777 3500 GAS 8.7 0.450 B28B 7920 3600 GAS 8.7 0.455 B30 8198 3600 GAS 8.4 0.439 Tyonek 8700 3600 GAS 8.0 0.414 TD 9080 3600 WATER 7.6 0.396 -' Offset Well Mud Densities Well MW range Top(ND) Bottom(ND) Date Beaver Creek 1B 9.2-9.9 ppg 5,200 10,900 2014 Beaver Creek 11 8.8-9.6ppg 400 8,684 2003 Beaver Creek 13 8.5-10.4ppg 0 10,182 2003 Beaver Creek 14A 9.0-9.4ppg 5,000 9,450 2014 BeaverCreek7A 9.0-9.3 2,400 8,929 2014 • Beaver Creek 12A 9.0-9.4 4,500 9,578 2014 Assumptions: 1. Fracture gradient at shoe is estimated at 0.65 psi/ft based on field test data. 2. Maximum planned mud density for the 8-1/2"hole section is 9.5 ppg. 3. Calculations assume"Unknown"reservoir contains 100%gas(worst case). 4. Calculations assume worst case event is 100%evacuation of wellbore to gas. Fracture Pressure at 9-5/8"shoe considering a full column of gas from shoe to surface: 3216(ft)x 0.65(psi/ft)= 2090 psi 2090(psi)-[0.1(psi/ft)*3216(ft)]= 1768 psi MASP from pore pressure(unknown gas sand at TD,at 8.4 ppg,encountered while drilling) r 9,080(ft)x 0.396(psi/ft)= 3596 psi C I 3596(psi)-[(2/3)*0.1(psi/ft)*9080(ft)]+[(1/3)*0.396(psi/ft)*9080(ft)]= 1792 psi MASP from pore pressure during production mode(Complete evacuation to gas) I//N]]T) t,l 4 9,080(ft)x 0.396(psi/ft)= 3596 psi / It 3596(psi)-[0.1(psi/ft)*9080(ft)]. 2688 psi Summary: 1. MASP while drilling 8-1/2"production hole is governed by pore pressure and evacuation of 2/3 wellbore to gas at 0.1 psi/ft. Page 49 Version 0 July, 2014 Beaver Creek#24 ii I- Drilling Procedure Rev 0 Hilcorp Energy Company 29.0 Spider Plot (NAD 27) (Governmental Sections) Legend — J BCU 24 SHL X BCU 24 TPH + BCU 24 BHI • • Other Surface Well Locations W E,ZUc:F2 BHL EDE r Other Bottom Hole Locations f,. ---- Wee Paths Oil and Gas Unit Boundary / , BCU 03BM/ Bw 1 / ew a /' r, / Bar 11 BMr / r 1 rr rf i rr! i / r t SOO7N010W A028083 /'r t r actme>em. O.• BCU 24 SHL BEAVER CREEK UNIT cU o4 eM1 �n * . ! ' / If •,, ecu oeeL. + f i fI '\ BCU 24 TPH N i 1 4, I / BCU 13eH CD 9 BCu is ma ` i sou osaML+ i rti_ BHt El BCU t4 HH t Bou 14hBF& { -+i✓ f / r//r WCU16 BFC r f�r/ 1t 1. "—..-- --'"/ ' :: '/ Ocu gyr`aFa- �� e BCU is BMW' a `�........, .,y am o1elMb 4 A028118 BCU oZ OMLC p SOOT N01 OW a BCU 07A.3141k. II 0 1,230 2300 Beaver Creek Unit Feet BCU24 Alaska State Plane Zone 4,MAtl27 Ihk.wp.11.1.41.16 1.1.17 Mao Dale:.7/10/2014 A Page 50 Version 0 July. 2014 Beaver Creek#24 tit F Drilling Procedure Rev 0 Hilcorp Energy Company 30.0 Surface Plat (As Built) (NAD 27) • :,,,2a-A2;;P I: • . — - SEr:TION LINE NOT TO SCALE • . • ' ' • . -- • ' '— • I .W 6 I.0 -D / v� I-• Nz I= SECTION 34 T7N R1OW SM,AK -t w .Z 6 // 1-- (i • B.C.U.NO.24 •1. BEAVER CREEK UNIT AS-BUILT ' PAD 3 r.•` N:2434055.893' " • E:317464.359' 1 _ . u. .� ,. / LAT:60'39'30.870r N FWL INTSI I • I LONG:-151'01.02.8417"W • "Y"° / / NA027 ASP Zone 4 / ( aw..S .... .m // ELEV_160.18'NAVD88 \tiu�� 1645'FWt. . ` .•... 7 1127 FNL i I /1\ 0 4111 04*,t ,.. �```_- � NOTES -"cV t1 BASIS OF GEODETIC CONTR,CL MC NAD83 POSITION(EPOCH 20331 IS AN OPUS SOLUTION FROM NOS COORDINATES STATIONS'KENT CORS ARP'.11.KA I TALKEETNA CORS ARP'AND`POTS POTATO POINT 3 ARP'TO ESTABLISH THE POSITION OF MCI BCI.THE GEODETIC POSITION OF BCI WAS DETERMINED TO HAVE A LATITUDE OF ' 60'2F754.027J7'N AND A LONGITUDE OF I 15113222.3J311'W THE A€nASKASTATE FtANE ���l��1{� _ COORDINATES IASP)ZONE 4ARE •• Sp''• Ni-• rII, �1 EI ELEV. 1313 1 .p 'r NORTH ELEV.131.31'INAVO68I I ,:"..1,...1. Ili :+. � ��ylG,/ � - . .._ :v 7) BASIS OF VERTICAL CONTROL IS NOS BM V8q a^ 1}f PID 770508 LOCATED WITHIN THE KENAI SPUR SIAM 0.1fcI.AN(% • it t4�7 5 HIGHWAY RIGHT OF WAY AT MILE POST 175 • i� �aAM.// oa HAVING AN ELEVATION OF 164.55 FEET NAVD I 4p�;� it I 55 ACCORDING TO P105 PUBLISHED DATA, III ��� J�to [ 3> COORDINATES COVERTED TO HAD 27 USING CORPS. SOFTWARE e BCU 1124 WELL AS-BUILT SURFACE LOCATION (NAD27) BEAVER CREEK INT PAD 3 i- ENGINEERING.TESTING LOCATION:SECTION 34, TOWNSHIP 7 NORTH, SURVPE' G-MAAPPING RANGE 10 WEST,SEWARD MERIDIAN ALASKA ]IHrnrp-110 la.1.11SflLooTNA.aK,996 JOB NO 143482 VOICE:190T)263-4218 FAX'MT)283-3265 DRAWN BY Casa*kie WYNV.MCLANECG.CCW B k1 M DATE:08008,14 ROURE: 1 Page 51 Version 0 July,2014 Beaver Creek#24 tit Drilling Procedure Rev 0 Hilcorp Energy Company 31.0 Surface Plat (As Built) (NAD 83) :N 243496910 SECTION�UNE NOT TO SCALA ' — ' ' — ' ' *'4°-• ' ' - E 145585653 • I "W -t I( .Q Io SECTION 34 T7N R 1 OW SM.AK Lt .Z 'J \ IF- ( \ B.C.U.NO.24 . BEAVER CREEK UNIT ..`-.. AS-BUILT I PAD 3 N 2433816.782' `'n L }. asi..,� E.1457485.525' 1 ;._.,.,, ,.,, W r, / LAT:60"3928.8235'N FINL(NTS) / } •• • / LONG:-15101'10.8578°W ac4.. / NAD83 ASP Zone 4 I • •°`"...•., -^ / ELEVr 18018'NAVD88 I •"••� 1645'FWL / 1127'FNL I1/\ actiaon '�v -/ NOTES 1I BASIS OF GEODETIC CONTROL AND NADS3 • POSITION(EPOCH 20031 IS AN OPUS SOLUTION FROM NGS COORDINATES 5TATK:NS"KENT OCAS ARP*.*TOM TALKEETNA CORS ARP",AND'POT3 POTA'0 POINT 3 ARP'TO ESTABLJSH THE POSITION or MCI 8[:1 THE GEODETIC POSITION co SCI WAS DETERMINED TO HAVE A LATITUDE OF I ``o�v,f,ti i E` 88'3850.02777'N AND A LONGITUDE OF I 151'92,12 30311'W.THE ALASKA gi`ATE PLANE 1 --'4Fa9f A�tiS Ire COORDINATES(ASP)ZONE4ARE • yy �� N-X2429853.534' •.F 49111 PII 1:* NOR TH Ea 1453863.065' �/- . FLEV.131.31'(NAVOe9) I �a 11¶AN A.x14c }1 --.1� 2 i BASIS OF VERTICAL CONTROLIS NGS Bk1 V93 • ',' - It/CA/f PID TTOSDS LOCATED WITHIN THE KENAI SPUR �I 'op. :I�:� -��- HIGHWAY RIGHT OF WAY AT MILE POST 3,75 I I Itis r�iaw`�� SC.A�E , HAVING AN ELEVATION OF 164.55 FEt I NAVD A8 ACCORDING TO NGS PUBLISHED DATA. III `L � fJ BCU 1124 WELL AS-BULT SURFACE LOCATION (NAD83) BEAVER CREEK LAIR PAD 3 ENGINEERING-TESTING LOCATION;SECTION 34. TOWNSHIP 7 NORTH, SURVEYING-MAPPING P.R.BOX 46K LOCATION: 10 WEST,SEWARD MERIDIAN ALASKA I III,-arp,%lasku.III Mc G. SOLDOTNA.AK.99659 JOB NO. 143I 82 ' VFAICE:(90 2283-4218 83 3 8 , Cana*/Inc 'IwWY.MCI.ANECG.COAI QR ABY BMM DATE:08.48.14 FK70.1RE11 Page 52 Version 0 July, 2014 RECEIVED SEP 0 4 2014 AOGCC Hilcorp Energy Company Beaver Creek Unit Beaver Creek Unit Beaver CK Unit 24 BCU 24 Plan: BCU 24 WP5.0 Standard Proposal Report 11 August, 2014 _ • Sperry Drilling Services ORIGINAL HALLIBURTON Proje Beaver Creek Unit IHueorpSite: Beaver Creek Unit Sperry IIrlineg Well: Beaver CK Unit 24 Wellbore: BCU 24 SECTION DETAILS BCU 24 WP5.0 Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target 1 18.60 0.00 0.00 18.60 0.00 0.00 0.00 0.00 0.00 CASING DETAILS 2 400.00 0.00 131.96 400.00 0.00 0.00 0.00 131.96 0.00 3 1322.41 27.67 136.09 1286.96 -157.37 151.51 3.00 136.09 218.27 TVD MD Name Size 4 3280.51 27.67 136.09 3021.10 -812.48 782.21 0.00 0.00 1126.89 BCU 24 Shallow Tgt wp3 3216.10 3500.00 9 5/8" 9-5/8 5 3346.26 27.26 131.90 3079.44 -833.54 804.01 3.00 -103.79 1157.20 9080.18 9674.69 51/2" 5-112 6 5792.71 27.28 131.90 5254.10 -1582.02 1638.13 0.00 0.00 2277.31 BCU 24 BC_B4ST Tgt wp3 7 6899.34 5.13 132.04 6310.21 -1787.00 1866.38 2.00 179.97 2583.94 8 8155.03 5.13 132.04 7560.86 -1862.21 1949.79 0.00 0.00 2696.20 9 8411.61 0.00 131.96 7817.10 -1869.90 1958.32 2.00 180.00 2707.68 ECU 24 Mid Tgt wp3 10 9674.70 0.00 131.96 9080.18 -1869.90 1958.32 0.00 131.96 2707.68 WELL DETAILS: Beaver CK Unit 24 66. Ground Level: 160.50 0- +N/-S +E/-W Northing Easting Latittude Longitude Slot 0.00 0.00 2434055.89 317464.36 60.6585752 -151.0174560 750-- Start Dir 3°/100':400'MD,400'TVD REFERENCE INFORMATION Co-ordinate(N/E)Reference: Well Beaver CK Unit 24,True North Vertical(ND)Reference: Plan:BCU 24 @ 179.10usft((160.5 GL+18.6 KB)) End Dir : 1322.41'MD, 1286.96'TVD Measured Depth Reference: Plan:BCU 24 @ 179.10usft((160.5 GL+18.6 KB)) 1500- Calculation Method: Minimum Curvature 2250- I Hilcorp Energy Company Start Dir 3°/100':3280.51'MD,3021.1'TVD Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Closest Approach 3D 3000- SHALLOW GAS Error Surface: Elliptical Conic Warning Method: Error Ratio End Dir :3346.26'MD,3079.44'TVD �_.._......._........... - 3750- BCU 24 Shallow Tgt wp3 c 9 5/8" 4500- 0 Start Dir 2°1100':5792.71'MD,5254.1'TVD ti, - c - B2 ..-_.. 5250........ BCU 24 BC B4ST Tgt wp3 134 End Dir :6899.34'MD,6310.21'TVD 6000- 2 - UBC3 6750- • Start 750- Start Dir 2°/100':8155.03'MD,7560.86'TVD B18 7500- BCU 24 Mid Tgt wp3 B24 .. End Dir :8411.61'MD,7817.1'TVD B28B 8250- B30 5 1/2" ' 9000 Tyonek Total Depth:96741'MD,9080.18'ND FORMATION TOP DETAILS 9750- BCU 24 WP5.0 • TVDPath MDPath Formation 3016,10 3274.87 SHALLOW GAS 5058.10 5572.22 82 5249.10 5787.09' 84 10500- SURVEY PROGRAM 6068.10 6655.03 UBC3 Date:2014-08-11700:00:00 Validated:Yes Version: 7264.10 7777.10 8 337171.6 71 814 .61 B24 Depth From Depth To Survey/Plan Tool 8 87 8230 11250 18.60 3500.00 BCU 24 WP5.0(BCU 24) MWD+SC+sag 81198.10 00.10 92992.61 4.61 830 3500.00 9674.70 BCU 24 WP5.0(BCU 24) MWD+SC+sag 8700.10 9294.61 Tyonek -1500 -750 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 Vertical Section at 133.76°(1500 usft/in) v:.-4''01' YY N O. (73E"' Q _ C �� WmN I 00 [>. 7 - CD dN0 00 N�1n b '-, — iiY r v QO N vi DC rn -- m 00004 zw10^0 Emr coca N co - ur V' I- A Zoo Jq' co co l'.: p 0\ - 0 766 i U 2nnd I- - vi - u '�M z D� I- > r �� Q 4 00 W U Y W 0 c co CN > N Q� w _ q U N N O V N E.r M .. co 4,-,'",N�� w >>>U z Oo° YI y'..un y p o W 000E (n �O'7 U 6-,10 4> O 4. -. _ W o 1- ,--1<e C] a,m o.5 U MW m 2 N vNi fV ., . e —g a.c12 m cc • C0 v , W - Z 0 > N N ._, J WO „, ! O -... N. —L. 8 O OD N 313 Md n IL 0Wc >- p UU Ni w c. OOCO eWv mm 0, ,,. m � 0> 0 N NO 0 0 V Q 0KO MW J vNi CL_IEwaot ?ods > WW �' ~ a3 c .. = M W F'O.yO- ..co c co O TNN _ 0 - p-j� ZO 2DD ~ l.. `00 �Hu 300 N - M _ N Uj N N N CO LT1m 0 Q . - U W O O O ✓ o. 0 'wo 0 .c 0 V' ,M. N ._.P g o a S( :. F" ,t"./ .... U M .5 O I`7 W ,n rY C J - W �7 > W u o a^ rn 2 o c pp C U 0-0 OO I _ —O Cb Q� 0.0 p `h Eoo N L` W £qq_W +O O M C I , - � e. .(n in LIa O W0000 - 8 ESa`p .c�M O Q - _ c_UO_t n L, - O 2 (n U W W Wfr, I N 0 m, N C ,M _— J LHtcL a ...6 3 3 - Elnmiq� C n ' ;� - a 0 c$c`c co w o K c > vwuiw.E cn QaQ 5. ' 0 U ,O oo r7' 00o A77 r+ 3 3 - O F 1 g Cd 'C _ P Q _.T.,. N a3 ch N ,--//' :.5 I- bo (.0::, _ a m m1 i-I .. . , d' —N 0 a rn N N CO - O - �y rn M W i —O MI F m co CO In :f) = ,e1 jOOn W 0Q* 0 0 0 0 WOON0Nm0N0O 0J _ Uo ows p.:r.:M(ti�� > NN,OnODWOO —__ $ F 1-�NNNNN 8888OW86 008 16,-6666600 - O W T .fh! 0— - 0 0,0000000000 W 0 0 0 0 0 0 0 0 0 0 - J QOOMOIh O(V ONO - q *4 -O >00 --.-WW W NN Q ?00NN V W CQ W W' W 00.-NOWI00000 O + ��0 0 0 W W W —W I- wLOOn00p N0�00 - 0.0 O,OOON W 01 - ZOO1tiIV'CLV 1'I`i W W 0?To x 00 00 , i , —_ 2 _ 1 �OOTOOO. W..O .QN F-woa4NLoon mc1pp00 - 0 j V11.1 '-MNOONM,O0 =V M {pnn of W • a _......0 0.. - -YOWOOWW00 O OIO NCO�- —N ® C...., 3 En 000MI000 ire COO WtO WtO NN6500 OO NNNNtO V)00 moo,-,,-0,...,0„, .„OO mil 0 —0 N.g W W...., a r)C ,,,nm— �WWUU - 0 �M�1O al co co 1I l l i l l 1 1 1 I 1 1 1 1 1 1 1 1 1 1 1 1 1 I I I I I I I I I l I I I I I I 1 1 1 I l l i i i I l l I j I I ooI 1111 L 0 oOc N 000 S 8 C „ �NtOO owsw W 0 Yl r O ^ K (( (uygsn OS(7) +)yLIoNA-)gMOs j 8 • d�Nc, M. CD CD UUUVa 0 R! c• ep m N �• mmiU 8 • ..- .....,(4 .- O N 4 N 8 rq No 8 b' Q+ ✓ C K f..l V N N G. J tir o U 0 N rn 0 h 1 - C o 1 1 v o - 0 0 v o .. vg CU N .' - y 3 0 0 -4; yrito,r O 0 00 / _-,,,,,_ , ,- „„-,,,,, oM 2 -_ pp O N MI 7-7 OMR L _ mij D =. p % OO O 0 O O O 8 O O O O O O O (ur/jsn OOP)(+)4. oN/(-)4anos Halliburton Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 24 - Company: Hilcorp Energy Company ND Reference: Plan:BCU 24 @ 179.10usft((160.5 GL+18.6 KB • Project: Beaver Creek Unit MD Reference: Plan:BCU 24 @ 179.10usft((160.5 GL+18.6 KB Site: Beaver Creek Unit North Reference: True ' Well: Beaver CK Unit 24 Survey Calculation Method: Minimum Curvature - Wellbore: BCU 24 Design: BCU 24 WP5.0 Project Beaver Creek Unit Map System: US State Plane 1927(Exact solution)' System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) • Using Well Reference Point Map Zone: Alaska Zone 04 Site Beaver Creek Unit Site Position: Northing: 2,430,086.36 usft Latitude: 60.6475877 From: Map Easting: 314,428.19usft Longitude: -151.0340284 Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -0.90 ° Well Beaver CK Unit 24 Well Position +N/-S 0.00 usft Northing: 2,434,055.89 usfl " Latitude: 60.6585752 +E/-W 0.00 usft Easting: 317,464.36 usfl • Longitude: -151.0174560 Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usfl Ground Level: . 160.50 usft Wellbore BCU 24 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (0) (nT) BGGM2014 6/12/2014 17.02 73.63 55,453 Design BCU 24 WP5.0 Audit Notes: Version: Phase: PLAN Tie On Depth: 18.60 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 18.60 0.00 0.00 133.76 Plan Sections Measured Vertical ND Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (usft) (0) (°) (usft) usft (usft) (usft) (°/100usft) (°/100usft) ('l100usft) (0) 18.60 0.00 0.00 18.60 -160.50 0.00 0.00 0.00 0.00 0.00 0.00 400.00 0.00 131.96 400.00 220.90 0.00 0.00 0.00 0.00 0.00 131.96 1,322.41 27.67 136.09 1,286.96 1,107.86 -157.37 151.51 3.00 3.00 0.45 136.09 3,280.51 27.67 136.09 3,021.10 2,842.00 -812.48 782.21 0.00 0.00 0.00 0.00 3,346.26 27.26 131.90 3,079.44 2,900.34 -833.54 804.01 3.00 -0.62 -6.36 -103.79 5,792.71 27.26 131.90 5,254.10 5,075.00 -1,582.02 1,638.13 0.00 0.00 0.00 0.00 6,899.34 5.13 132.04 6,310.21 6,131.11 -1,787.00 1,866.38 2.00 -2.00 0.01 179.97 8,155.03 5.13 132.04 7,560.86 7,381.76 -1,862.21 1,949.79 0.00 0.00 0.00 0.00 8,411.61 0.00 131.96 7,817,10 7,638.00 -1,869.90 1,958.32 2.00 -2.00 0.00 180.00 9,674.70 0.00 131.96 9,080.18 8,901.08 -1,869.90 1,958.32 0.00 0.00 0.00 131.96 8/11/2014 2::36:02PM Page 2 COMPASS 5000.1 Build 70 Halliburton Hisiii.19 Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 24 Company: Hilcorp Energy Company TVD Reference: Plan:BCU 24 @ 179.10usft((160.5 GL+18.6 KB Project: Beaver Creek Unit MD Reference: Plan:BCU 24 @ 179.10usft((160.5 GL+18.6 KB Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 24 Survey Calculation Method: Minimum Curvature Wellbore: BCU 24 Design: BCU 24 WP5.0 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (°) (0) (usft) usft (usft) (usft) (usft) (usft) -160.50 18.60 0.00 0.00 18.60 -160.50 0.00 0.00 2,434,055.89 317,464.36 0.00 0.00 100.00 0.00 131.96 100.00 -79.10 0.00 0.00 2,434,055.89 317,464.36 0.00 0.00 200.00 0.00 131.96 200.00 20.90 0.00 0.00 2,434,055.89 317,464.36 0.00 0.00 300.00 0.00 131.96 300.00 120.90 0.00 0.00 2,434,055.89 317,464.36 0.00 0.00 400.00 0.00 131.96 400.00 220.90 0.00 0.00 2,434,055.89 317,464.36 0.00 0.00 Start Dir 3°1100':400'MD,400'TVD 500.00 3.00 136.09 499.95 320.85 -1.89 1.82 2,434,053.98 317,466.14 3.00 2.62 600.00 6.00 136.09 599.63 420.53 -7.54 7.26 2,434,048.24 317,471.50 3.00 10.45 700.00 9.00 136.09 698.77 519.67 -16.94 16.31 2,434,038.70 317,480.40 3.00 23.49 800.00 12.00 136.09 797.08 617.98 -30.07 28.95 2,434,025.38 317,492.84 3.00 41.70 900.00 15.00 136.09 894.31 715.21 -46.88 45.13 2,434,008.32 317,508.76 3.00 65.02 1,000.00 18.00 136.09 990.18 811.08 -67.34 64.83 2,433,987.56 317,528.14 3.00 93.40 1,100.00 21.00 136.09 1,084.43 905.33 -91.38 87.98 2,433,963.16 317,550.91 3.00 126.75 1,200.00 24.00 136.09 1,176.81 997.71 -118.95 114.52 2,433,935.18 317,577.02 3.00 164.98 1,300.00 27.00 136.09 1,267.06 1,087.96 -149.96 144.37 2,433,903.71 317,606.39 3.00 207.99 1,322.41 27.67 136.09 1,286.97 1,107.87 -157.37 151.51 2,433,896.19 317,613.42 3.00 218.27 End Dir : 1322.41'MD,1286.96'ND 1,400.00 27.67 136.09 1,355.68 1,176.58 -183.33 176.50 2,433,869.85 317,638.00 0.00 254.28 1,500.00 27.67 136.09 1,444.24 1,265.14 -216.79 208.71 2,433,835.90 317,669.69 0.00 300.68 1,600.00 27.67 136.09 1,532.80 1,353.70 -250.24 240.92 2,433,801.95 317,701.38 0.00 347.08 1,700.00 27.67 136.09 1,621.37 1,442.27 -283.70 273.13 2,433,768.00 317,733.07 0.00 393.49 1,800.00 27.67 136.09 1,709.93 1,530.83 -317.16 305.34 2,433,734.05 317,764.75 0.00 439.89 1,900.00 27.67 136.09 1,798.49 1,619.39 -350.61 337.55 2,433,700.09 317,796.44 0.00 486.29 2,000.00 27.67 136.09 1,887.05 1,707.95 -384.07 369.76 2,433,666.14 317,828.13 0.00 532.70 2,100.00 27.67 136.09 1,975.61 1,796.51 -417.52 401.97 2,433,632.19 317,859.82 0.00 579.10 2,200.00 27.67 136.09 2,064.18 1,885.08 -450.98 434.18 2,433,598.24 317,891.51 0.00 625.50 2,300.00 27.67 136.09 2,152.74 1,973.64 -484.44 466.39 2,433,564.29 317,923.19 0.00 671.90 2,400.00 27.67 136.09 2,241.30 2,062.20 -517.89 498.60 2,433,530.34 317,954.88 0.00 718.31 2,500.00 27.67 136.09 2,329.86 2,150.76 -551.35 530.81 2,433,496.39 317,986.57 0.00 764.71 2,600.00 27.67 136.09 2,418.42 2,239.32 -584.81 563.02 2,433,462.44 318,018.26 0.00 811.11 2,700.00 27.67 136.09 2,506.99 2,327.89 -618.26 595.23 2,433,428.49 318,049.95 0.00 857.52 2,800.00 27.67 136.09 2,595.55 2,416.45 -651.72 627.44 2,433,394.54 318,081.63 0.00 903.92 2,900.00 27.67 136.09 2,684.11 2,505.01 -685.17 659.65 2,433,360.59 318,113.32 0.00 950.32 3,000.00 27.67 136.09 2,772.67 2,593.57 -718.63 691.86 2,433,326.64 318,145.01 0.00 996.73 3,100.00 27.67 136.09 2,861.23 2,682.13 -752.09 724.07 2,433,292.69 318,176.70 0.00 1,043.13 3,200.00 27.67 136.09 2,949.80 2,770.70 -785.54 756.28 2,433,258.74 318,208.39 0.00 1,089.53 3,274.87 27.67 136.09 3,016.10 2,837.00 -810.59 780.39 2,433,233.32 318,232.11 0.00 1,124.27 SHALLOW GAS / 3,280.51 27.67 136.09 3,021.10 2,842.00 -812.48 782.21 2,433,231.40 318,233.90 0.00 1,126.89 Start Dir 3°/100':3280.51'MD,3021.1'TVD 3,300.00 27.54 134.86 3,038.37 2,859.27 -818.92 788.54 2,433,224.87 318,240.13 3.00 1,135.92 3,346.26 27.26 131.90 3,079.44 2,900.34 -833.54 804.01 2,433,210.01 318,255.37 3.00 1,157.20 End Dir :3346.26'MD,3079.44'ND 3,400.00 27.26 131.90 3,127.21 2,948.11 -849.98 822.33 2,433,193.28 318,273.44 0.00 1,181.81 8/11/2014 2.36:02PM Page 3 COMPASS 5000.1 Build 70 Halliburton Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 24 Company: Hilcorp Energy Company TVD Reference: Plan:BCU 24 @ 179.10usft((160.5 GL+18.6 KB Project: Beaver Creek Unit MD Reference: Plan:BCU 24 @ 179.10usft((160.5 GL+18.6 KB Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 24 Survey Calculation Method: Minimum Curvature Wellbore: BCU 24 Design: BCU 24 WP5.0 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 3,037.00 3,500.00 27.26 131.90 3,216.10` 3,037.00 -880.57 856.43 2,433,162.17 318,307.05 0.00 1,227.59 9 5/8" 3,600.00 27.26 131.90 3,304.99 3,125.89 -911.17 890.52 2,433,131.05 318,340.67 0.00 1,273.38 3,700.00 27.26 131.90 3,393.88 3,214.78 -941.76 924.62 2,433,099.93 318,374.29 0.00 1,319.16 3,800.00 27.26 131.90 3,482.77 3,303.67 -972.36 958.71 2,433,068.81 318,407.90 0.00 1,364.95 3,900.00 27.26 131.90 3,571.66 3,392.56 -1,002.95 992.81 2,433,037.69 318,441.52 0.00 1,410.73 4,000.00 27.26 131.90 3,660.55 3,481.45 -1,033.55 1,026.90 2,433,006.57 318,475.14 0.00 1,456.52 4,100.00 27.26 131.90 3,749.44 3,570.34 -1,064.14 1,061.00 2,432,975.45 318,508.76 0.00 1,502.30 4,200.00 27.26 131.90 3,838.33 3,659.23 -1,094.74 1,095.09 2,432,944.33 318,542.37 0.00 1,548.09 4,300.00 27.26 131.90 3,927.22 3,748.12 -1,125.33 1,129.19 2,432,913.21 318,575.99 0.00 1,593.87 4,400.00 27.26 131.90 4,016.11 3,837.01 -1,155.92 1,163.28 2,432,882.10 318,609.61 0.00 1,639.66 4,500.00 27.26 131.90 4,105.00 3,925.90 -1,186.52 1,197.38 2,432,850.98 318,643.23 0.00 1,685.44 4,600.00 27.26 131.90 4,193.89 4,014.79 -1,217.11 1,231.47 2,432,819.86 318,676.84 0.00 1,731.23 4,700.00 27.26 131.90 4,282.78 4,103.68 -1,247.71 1,265.57 2,432,788.74 318,710.46 0.00 1,777.01 4,800.00 27.26 131.90 4,371.67 4,192.57 -1,278.30 1,299.66 2,432,757.62 318,744.08 0.00 1,822.80 4,900.00 27.26 131.90 4,460.57 4,281.47 -1,308.90 1,333.76 2,432,726.50 318,777.69 0.00 1,868.58 5,000.00 27.26 131.90 4,549.46 4,370.36 -1,339.49 1,367.85 2,432,695.38 318,811.31 0.00 1,914.37 5,100.00 27.26 131.90 4,638.35 4,459.25 -1,370.09 1,401.95 2,432,664.26 318,844.93 0.00 1,960.15 5,200.00 27.26 131.90 4,727.24 4,548.14 -1,400.68 1,436.04 2,432,633.15 318,878.55 0.00 2,005.94 5,300.00 27.26 131.90 4,816.13 4,637.03 -1,431.28 1,470.14 2,432,602.03 318,912.16 0.00 2,051.73 5,400.00 27.26 131.90 4,905.02 4,725.92 -1,461.87 1,504.23 2,432,570.91 318,945.78 0.00 2,097.51 5,500.00 27.26 131.90 4,993.91 4,814.81 -1,492.47 1,538.33 2,432,539.79 318,979.40 0.00 2,143.30 j 5,572.22 27.26 131.90 5,058.10 4,879.00 -1,514.56 1,562.95 2,432,517.32 319,003.68 0.00 2,176,36 B2 5,600.00 27.26 131.90 5,082.80 4,903.70 -1,523.06 1,572.42 2,432,508.67 319,013.02 0.00 2,189.08 5,700.00 27.26 131.90 5,171.69 4,992.59 -1,553.66 1,606.52 2,432,477.55 319,046.63 0.00 2,234.87 5,787.09 27.26 131.90 5,249.10 5,070.00 -1,580.30 1,636.21 2,432,450.45 319,075.91 0.00 2,274.74 B4 5,792.71 27.26 131.90 5,254.10 5,075.00 -1,582.02 1,638.13 2,432,448.70 319,077.80 0.00 2,277.31 Start Dir 2°/100':5792.71'MD,5254.1'TVD 5,800.00 27.12 131.90 5,260.58 5,081.48 -1,584.25 1,640.61 2,432,446.44 319,080.24 2.00 2,280.64 5,900.00 25.12 131.91 5,350.37 5,171.27 -1,613.65 1,673.37 2,432,416.53 319,112.55 2.00 2,324.64 6,000.00 23.12 131.91 5,441.63 5,262.53 -1,640.94 1,703.78 2,432,388.77 319,142.53 2.00 2,365.48 6,100.00 21.12 131.91 5,534.27 5,355.17 -1,666.09 1,731.80 2,432,363.19 319,170.16 2.00 2,403.11 6,200.00 19.12 131.92 5,628.16 5,449.06 -1,689.06 1,757.39 2,432,339.82 319,195.39 2.00 2,437.49 6,300.00 17.12 131.92 5,723.20 5,544.10 -1,709.84 1,780.53 2,432,318.69 319,218.21 2.00 2,468.57 6,400.00 15.12 131.93 5,819.26 5,640.16 -1,728.39 1,801.18 2,432,299.83 319,238.57 2.00 2,496.31 6,500.00 13.12 131.94 5,916.24 5,737.14 -1,744.69 1,819.33 2,432,283.25 319,256.46 2.00 2,520.69 6,600.00 11.12 131.95 6,014.00 5,834.90 -1,758.72 1,834.94 2,432,268.98 319,271.86 2.00 2,541.67 6,655.03 10.02 131.96 6,068.10 5,889.00 -1,765.47 1,842.45 2,432,262.11 319,279.26 2.00 2,551.76 UBC3 6,700.00 9.12 131.97 6,112.44 5,933.34 -1,770.46 1,848.01 2,432,257.03 319,284.74 2.00 2,559.23 6,800.00 7.12 131.99 6,211.44 6,032.34 -1,779.91 1,858.51 2,432,247.43 319,295.09 2.00 2,573.35 6,899.34 5.13 132.04 6,310.20 6,131.10 -1,787.00 1,866.38 2,432,240.21 319,302.85 2.00 2,583.94 End Dir :6899.34'MD,6310.21'TVD 8/11/2014 2::36:02PM Page 4 COMPASS 5000.1 Build 70 Halliburton tib Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 24 Company: Hilcorp Energy Company TVD Reference: Plan: BCU 24 @ 179.10usft((160.5 GL+18.6 KB Project: Beaver Creek Unit MD Reference: Plan: BCU 24 @ 179.10usft((160.5 GL+18.6 KB Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 24 Survey Calculation Method: Minimum Curvature Wellbore: BCU 24 Design: BCU 24 WP5.0 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (0) (0) (usft) usft (usft) (usft) (usft) (usft) 6,131.76 6,900.00 5.13 132.04 6,310.86 6,131.76 -1,787.04 1,866.42 2,432,240.17 319,302.90 0.01 2,584.00 7,000.00 5.13 132.04 6,410.46 6,231.36 -1,793.03 1,873.07 2,432,234.08 319,309.45 0.00 2,592.94 7,100.00 5.13 132.04 6,510.06 6,330.96 -1,799.02 1,879.71 2,432,227.99 319,316.00 0.00 2,601.88 7,200.00 5.13 132.04 6,609.66 6,430.56 -1,805.01 1,886.35 2,432,221.90 319,322.54 0.00 2,610.82 7,300.00 5.13 132.04 6,709.26 6,530.16 -1,811.00 1,893.00 2,432,215.80 319,329.09 0.00 2,619.76 7,400.00 5.13 132.04 6,808.86 6,629.76 -1,816.99 1,899.64 2,432,209.71 319,335.64 0.00 2,628.70 7,500.00 5.13 132.04 6,908.46 6,729.36 -1,822.98 1,906.28 2,432,203.62 319,342.19 0.00 2,637.64 7,600.00 5.13 132.04 7,008.06 6,828.96 -1,828.97 1,912.92 2,432,197.53 319,348.74 0.00 2,646.58 7,700.00 5.13 132.04 7,107.66 6,928.56 -1,834.96 1,919.57 2,432,191.44 319,355.29 0.00 2,655.52 7,800.00 5.13 132.04 7,207.25 7,028.15 -1,840.95 1,926.21 2,432,185.35 319,361.84 0.00 2,664.46 7,857.07 5.13 132.04 7,264.10 7,085.00 -1,844.36 1,930.00 2,432,181.87 319,365.58 0.00 2,669.56 B18 7,900.00 5.13 132.04 7,306.85 7,127.75 -1,846.94 1,932.85 2,432,179.26 319,368.39 0.00 2,673.40 8,000.00 5.13 132.04 7,406.45 7,227.35 -1,852.92 1,939.50 2,432,173.16 319,374.94 0.00 2,682.34 8,100.00 5.13 132.04 7,506.05 7,326.95 -1,858.91 1,946.14 2,432,167.07 319,381.49 0.00 2,691.28 8,155.03 5.13 132.04 7,560.86 7,381.76 -1,862.21 1,949.79 2,432,163.72 319,385.09 0.00 2,696.20 Start Dir 2°/100':8155.03'MD,7560.86'TVD 8,200.00 4.23 132.04 7,605.68 7,426.58 -1,864.67 1,952.52 2,432,161.22 319,387.78 2.00 2,699.87 8,300.00 2.23 132.04 7,705.52 7,526.42 -1,868.44 1,956.71 2,432,157.38 319,391.91 2.00 2,705.51 8,371.61 0.80 132.04 7,777.10 7,598.00 -1,869.71 1,958.11 2,432,156.09 319,393.30 2.00 2,707.40 B24 8,400.00 0.23 132.04 7,805.49 7,626.39 -1,869.88 1,958.30 2,432,155.92 319,393.48 2.00 2,707.66 8,411.61 0.00 0.00 7,817.10 7,638.00 -1,869.90 1,958.32 2,432,155.90 319,393.50 2.00 2,707.68 End Dir :8411.61'MD,7817.1'TVD 8,500.00 0.00 131.96 7,905.49 7,726.39 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 8,514.61 0.00 131.96 7,920.10 7,741.00 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 B28B 8,600.00 0.00 131.96 8,005.49 7,826.39 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 8,700.00 0.00 131.96 8,105.49 7,926.39 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 8,792.61 0.00 131.96 8,198.10 8,019.00 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 B30 8,800.00 0.00 131.96 8,205.49 8,026.39 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 8,900.00 0.00 131.96 8,305.49 8,126.39 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 9,000.00 0.00 131.96 8,405.49 8,226.39 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 9,100.00 0.00 131.96 8,505.49 8,326.39 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 9,200.00 0,00 131.96 8,605.49 8,426.39 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 9,294.61 0.00 131.96 8,700.10 8,521.00 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 Tyonek 9,300.00 0.00 131.96 8,705.49 8,526.39 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 9,400.00 0.00 131.96 8,805.49 8,626.39 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 9,500.00 0.00 131.96 8,905.49 8,726.39 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 9,600.00 0.00 131.96 9,005.49 8,826.39 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 9,674.69 0.00 131.96 9,080.18 8,901.08 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 Total Depth:9674.7'MD,9080.18'ND-5 1/2" /9,674.70 0.00 131.96 9,080.18 • 8,901.08 -1,869.90 1,958.32 2,432,155.90 319,393.50 0.00 2,707.68 8/11/2014 2:36:02PM Page 5 COMPASS 5000.1 Build 70 Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 24 Company: Hilcorp Energy Company TVD Reference: Plan:BCU 24 @ 179.10usft((160.5 GL+18.6 KB Project: Beaver Creek Unit MD Reference: Plan:BCU 24 @ 179.10usft((160.5 GL+18.6 KB Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 24 Survey Calculation Method: Minimum Curvature Wellbore: BCU 24 Design: BCU 24 WP5.0 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) BCU 24 BCB4ST Tgt wp3 0.00 0.00 5,254.10 -1,582.02 1,638.13 2,432,448.70 319,077.80 -plan hits target center -Circle(radius 50.00) BCU 24 Shallow Tgt wp3 0.00 0.00 3,021.10 -812.48 782.21 2,433,231.40 318,233.90 -plan hits target center -Circle(radius 50.00) BCU 24 Mid Tgtwp3 0.00 0.00 7,817.10 -1,869.90 1,958.32 2,432,155.90 319,393.50 -plan hits target center -Circle(radius 50.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (') 9,674.69 9,080.18 5 1/2" 5-1/2 8-1/2 3,500.00 3,216.10 9 5/8" 9-5/8 12-1/4 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (usft) (usft) Name Lithology (°) (°) 8,371.61 7,777.10 B24 8,792.61 8,198.10 B30 9,294.61 8,700.10 Tyonek 5,572.22 5,058.10 B2 7,857.07 7,264.10 B18 6,655.03 6,068.10 UBC3 3,274.87 3,016.10 SHALLOW GAS 5,787.09 5,249.10 B4 8,514.61 7,920.10 B28B Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 400.00 400.00 0.00 0.00 Start Dir 3°/100':400'MD,400'TVD 1,322.41 1,286.97 -157.37 151.51 End Dir : 1322.41'MD, 1286.96'TVD 3,280.51 3,021.10 -812.48 782.21 Start Dir 3°1100':3280.51'MD,3021.1'TVD 3,346.26 3,079.44 -833.54 804.01 End Dir :3346.26'MD,3079.44'TVD 5,792.71 5,254.10 -1,582.02 1,638.13 Start Dir 2°/100':5792.71'MD,5254.1'TVD 6,899.34 6,310.20 -1,787.00 1,866.38 End Dir :6899.34'MD,6310.21'TVD 8,155.03 7,560.86 -1,862.21 1,949.79 Start Dir 2°/100':8155.03'MD,7560.86'TVD 8,411.61 7,817.10 -1,869.90 1,958.32 End Dir :8411.61'MD,7817.1'TVD 9,674.69 9,080.18 -1,869.90 1,958.32 Total Depth:9674.7'MD,9080.18'TVD 8/11/2014 2..36:02PM Page 6 COMPASS 5000.1 Budd 70 N 2 co0 5 L 01 L Q L ii frit __ v w E c N c O t.--4i; , u . O 4. U 0 ■ E i6 N2 0CV g � acD O N O W p fli m o cp o Es A CU L i (I) • N d cv m co m .= c) O �O C O c M O N _E O O = M � V = 0uj ci co a W � o � C a / E re ,. ,, ,T). = .,,,,, . c..., co .r. -.-. .5 u- :c=c /// m V N N O O a.+ h. cl y c L L c c sem` i C.) 0 � _ "' °' � a LV = = iJ M �LA 37cE 0 N mi N C N_ O W 0 V O y0 /� �L �G = . , n` y v m m m .a LL 0. d a) _ 14 L c ° CD CD a p o m N E N LI m' m o I= L L Y C 0 O 0 0 0 L v • o N c O N L L L IlD C •- c r N O v d G) a) N N `^^V�� — a) '5 c v a s ca iv Rf = _ - = C Q Ti; d v E re w _ ~ ~ .▪� s T ♦ 1 0 0 .,:-. . ,,,,3 i z N i mmmm m (� U Q ; v � > H i4 C p (/) I a- a) c O O N LC`a U U U ca C OA a) o s.. 2 a.) al C a W CO 0 rte..+ CO N N N N N U) N N N N N N N N N N N N N N N N N N N N N N N N N U) N N N N N N N N N NN N N N N N N U) N N N N N N L COco c COc m CO CO C m m m coL6 co CO CO CORS CO CO CO co CO m m co m p a a a a a a a a a a a a a a a a a a a a a a a a a a a a C4 ,..,'''. C 1.6 .6 o v C C C C ` C C C C C C Ny = O O 0 O o a) O o "O O ,O 0 O O p O d raO 0 O O 0 N ,O f6 7 o iU o R) 5 O @ U O N U 0 73 t) 0 N V i6 o V N o V N V U N C1 E N Q � �6 Q W CO CO LL CO Q � < C LL YO e LL Q W N Q LL < CO W CO a 'E N_ N a) N_ a) a) _N a> a) _N a) 0 N N a) _N a) a) a) a) N_ a) a) _N a) a) N a) co () C E a) a) c 0 a) c6 0 0 C ) 0 C a) 0 co0 a> co a) c6 0 a) C ) a> C 0 o E c a. M E. _n aas c a d c a c n c _Q a) n m e a c o. c o. N U W U U W U U Lu U U W U CJ Cu- U U W U W U U CO U C) W U CD U Co- oO C) LC) N N O N CO O CO a) CO c0 Sr h h N N Sr CO CO h Sr Sr N CO 0CO M Sr CO CO CO CO CO CO h N O 0 N V' CO 0 10 O) N 0 CO h O LO CO CD L- e- CO e- (fl CO Sr N h O CO O N C) e e- CO a) M LO CO O e- e- h O) oo h M C) c0 N O h M h h M V' h (Ni LO N CT h M h V' V' - .- O M C N CO O R C) LO CO N L!) CO Sr h h N CO O e- N Sr h CO N `- `- `- M LO CO N N U 13 CA N O N LO Sr CO CO e- O au O a) W C) N ,- NON O h CO O N y co O O O N O CO CO N CO CO N O W CO CO e- h V; CO O N M CO N . c L Ln N N h M O Sr V' CO Sr O e- Sr CO M N os-iN O O CO O O CO CA co M LO h c- CO V V' h N V' ,- N V' N N CO V CO h N N h e- V' e- e- V L6 a N Sr Sr co N tb LO t0 V' d' M O O N to O Cb y d O M O) CO- (A '- pE 0 V CO C co M CO U) Ln CO C) N N N N CO LO O O CO Cn CO M Sr M O O N Sr N N Sr d 0 O O O O W O h h O h h N h h N M CO Cb (T h h Cp V' V' d• V' V' N e- O O CO CO CO N V. V' M V' V' CO CO CO 0) e- e- d• d• V h N- 2_ CO N h a R N e- N N N O e N e- e- CD r- C6 z ., w d CD d 0 1.0 E -0 N O O O O CT 0 0 0 0 0 0 0 0 0 0 0 Sr O V' O O O O O O O N M O) O O CO O O M O N 0 0 0 0 0 0 0 0 0 00C> 0) 00 CO O O CO O a. G = « O Ln O) O Ln tri V'LCO O LO U) c:6 LO LO O O N to M LOO W LO O CO O0 N Z M CO N N O N Sr N N N LO N N LO N- N 0 In LO N N N N- r- LO O r- 0 CO N l6 N Sr Sr N CO CO LO L!') (fl e- N r- o Sr co CO CO co co co a. y 0 ` CO. o) co" C) Ct g N 2� o N CO LO OO h N CO M N Sr N O M W CO M O CO N M O CO M O O n ca e- e- N CO CO h 0 N CO M O O CO CO e- ,- CO O CO N 0) O CO e- e- CO e- e- G d N N VO O 4 O O M Cp CO N CO 00 W VVO M VM O LO O LO LOU co = V- NNMNhSrV SrCO '71' 0:D0000Sr NN In hhONN LY U a a Cco1)3 cn N SrNO 1 w N _ p d. W = W K N O O O O 0) O O O O O C7 O O O O O V' O V' O O O O O O O U _ ;O m m d O) O O M O O M O h 0 0 0 0 0 0 0 0 0 Cb O 0) O O O O O C0 O M O LO O O C.0 LO V' Ln O IC In O LO LO O O N LO M to LO co O O CA O .c v•p 0) tp Q VM LO h N O h V' h h N LO N t0 h N 0 t0 L1') h N N h e- LO O .- LO N « N O N Sr Sr h CO CO LO LO (.0 e- N ,- e- Sr CO CO CO CO CO CO 2 U .C. d p r) a) M of U O N N L C G C 41 0 s 0) CoC N CU C U a v 0 ItD ` 41 p «`O oao OOo > -a ii 0 a a a V V V U 0 d u. £ CO O CO > > > 0 0 O c m 0 Z O O O e- - - M M M CO CO M 0 0 : W W W a) a) N N N a' co C• •C O DDDDDD DDDDDD m m m D D D DDDDD (",, M M UDO U •F, 0 16 p m Q . . 000 00000 m m N Y, = N CO CO m CO CO CO CO CO CO CO m CO m m m m m m m m 000 N 0 U U U U U U U U U U U U f/ a' OZ. a9 O V O O O e- e- M M co CO CO CO CO CD CO _� CO CO O_ Q) N N N CO CO m tiC) £ V n a) DDDDDD oooooD DDDDDD DDDDD MMMMM axv o y n O R ++ U U U U U U U U U U U U C) U U U C.) U U U U U U DDD > > C mm mmmm mmmmmm mmmmmm mmmmm UUUUU OO CO ,O = O O O M M M CO co co co co O Cb CO co CT _O N N N M M M M M N _ j »J «. rt-,... .J ... .-. ... ... .-. .� ... »-. ... Arc «. .-. «. .-� ... c C c c c c cc c c c c c c c c c c c c c c c C CCC •(n • c)O C i (NI a—DD a-- N 0 0 0 0 0 0 0 0 0 0 Un o y o rn d 0 U YYY YY Y YYYYYY Y Y YYYY YY Y Y Y YYY YY p) aO0 ai E N 1- 000000 000000 000000 00000 00000 C O a y C'13 z Q- > a`> a`) as as N as a`> as as N ) 0 N as 0> N N N N N N d N N N N N N U Q co Cr' > > > > > > > > > > > > > > > > > > > > > > > > > > > > N N RR' d.. E d aa) aa)) aa)CO N CO CO CO CO aa> aa) aa) aCIS CO @> CO N a) N CO N CO CO CO CO CO aa) aa) CO CO CO a0) aa) C N w C C to U CO m m m m m m m m m m m m m m m m m m m m m m m m m m m m O (vs0 Cu U R co N C 0 T cc CO 0 O i R U V U aaA a)• 0 t. C a W m a.m CO V) V) V) V) V) N V) U) V) V) N U) V) oY U) V) N U) V) U) V) U) V) V) V) V) V) L CO ro ro CO ro CO CD CO CO ro CZ CZ CO 0 ddddddn. aaa. a. aa C..) C = 0 -p Cc c c v°'i E o n `a a) 3 `a c., .3 `p a, ° `o CO 7 p 0 N V 0 N CO C N U C 0 U C13 E I.L. as N LL ca (6 (L CD CO u CO O) L.L. N N•C N 7, a0 N N O O N O (U O E ro O O ro °_.' O ro 2 (U ro d CU ro O 0 C a C a_ C a C a_ N i- 7 N UU) U W U U WO U W O O W O rn cm y+U o Cp CA O CO 0) N 'Cl' N O N N 0 N CO 0 0 (n (n (n N CO V' CO = L O (O O N N (O - V a) CO (O (n ( 0 0 CO UCO CO N 6 M O N W oM M + +CO dCO N 't d' N O n N V V N r0c) 0 CO 0u. > > V -Ou) co (O (O co (n (O O O (7 n y (O (n 0 N (n 0 N CT CT (n O O Cr) M CO 0 u) 6 0 (n 6 4 4 (() a) cO N-.E . co O <t co O V _ .4-(O a) N O (n eaQ y V v a) v V O M 4 O V V O y • Q 7 .- M V O) r O .- M CO N 0) V' N M W f. C (O .r CO N N (O V 0 Cr) N O O N O 2 00 0 N O O N W W N r-. 6 .- N a) (.0 CO 0 CO CO O (a � N O a) CO O. N N N N a) ro W N la ci) co 0 4) . • O V' O O V O O O O O (n O O CO N O O O V O O O O O 0 O O C O a ; y 6 666 6o � o6 6 6a6 (h N R Q N V' O) V V a) V V 0 V V N O M a N i Q - 0 pO NN R �) 3U C o co N r (O M N (n M (O M CT 40 (O @ O, 0 M (n O M 0 O 0 0 CO N n (d U V d U) 7 C w N (Co- CLai 4 CO N CO CO N Co CO OC) 00) 00) N U) CO O E La 0 d a 'C _y (Oi) W N _ Q d iz Q X O O O W N mm co v 0v00 .700 000 (n00 da co o ;g 0 v 0 0 v 0 0 0 0 0 CS) 0 0 ro c = N •p 7 Q r N cri O � t- O ((a N O N N O O i� V (U ` E a)_ 0 A y 7 .- V' V' 0 V .f 0) V C' O 4 V' N N N O d D S yQr.. — M au 2 ro m U V N N m Umm C' c3z L � •l (/) a m U CD = p O N O N c (0 Y a O= o N ° m �° 'c y (n CO Vj U U) COCD d Q O in ~ co-0 p O Q 7 O (L E 0 0 0 0 ro L a a co L C m N 0 Z 2 Q' 2' Q' �• N O) 2 O c 4 c "� O ( ro C `) M ((') LC) 0 L O O N U CU - `O V) « y C 'c g '� 0 U LO (n (n U U U (o (o (o 0) 0) a) 0 N a� v a � M • CO m » D m m m » > » > O E °0O o m aro) m (n Y N d 61 , 000 . . . 000000 ) p y ton N t O wd7U ammm000 mmmmmm L. ; p N a n E 0 n (n (n (fin (fin (fin (fl CO CO 0) 0) rn 0 CI) c -c m -CB v COas XO ti E Q Q 'Ir O O N N U N 4 Ce > (O U U U U U U U U U U V U U e 2 C (3 ° 0Lei Z mmmmmmm mmmmmm G) o o m N 0 m U =y ('7 to (n (n (n (n (n co (o co 0) 0) 0 C 7 N Q) O 0• t C O ` C C C C C C C C C C C C C (n N NI U) N C II C 1-4 ..... O dO Qy YYYYY YYYYYY UUUUUUU UVVUVU Y - ofl-. ( o)7 0 Q y N ¢ ca°' z aoa a s o00 8 oo ` a N ro p , c ocm Q > > > > > > > > > > > > > aaarooVv4.0 C Ca al N ` W 4 y a; E ommam aa aororomro0 O m a) a m mc y C C CO 0 m m CO m CO m CO CO CO CO CO m m Q 7 0 0 ro N ro O V) O) _ < Ucev) v) W U (n 0 U Q CO C .a' (l) o o 0 U .. > > U s U cK q > > bin '" > > > > rD > > 5 aCC `- `- s-- `- '-- M O M p In p p C D D > > m D D D M U U m rn W GZ mmmmcKmmmmm O ty 0 O 0 C„ Cl o M (. co co- c$ co- CO CO m CO 6 Z D D D D D D D j M M Iri In Ifl rr U vw 000000 (-) C.) vUv0 C0 o co- La ai c� m m m Inm m N M CO In In ID p Ww c r -. .. w. C C C C C C C C C C C C C C R (o co (o co (o co co co co (o co co co co p (1) al N N a) a) a) a) a) N a) a) a) a) CD m m CO CO m CO CO m m CO CO CO CO m III 41 4 I 1 I N I I ..0 I I D Y I I U , I ��RG+ —--- _—V > I I I ro - r - 0 I cu co i I - 0 � h o in/ 2 I I •i- O. li co o I I I a a. co c N `m 1 I I I nco -,-. -- - - CO L - - N Y O co pDili + o p J NCU J ciiiI 1 I []�) - m o , CCN�J I' Q m 0 ri Q N 0_ co0 1 I I M coIX ct fa3 a) ip o 1 3 = N D p 1 CY 03C N N 7 1 1 O -o CI) CN N v L >+ `0 O a 0 c n a O M m a) a� 4 o o 2 76 (ui,gjsn 05E) uoileaedag aaqua° of aaqua° C U U0 0 C Q 6 > U U 0) c 'E 0) el a o U o o a) o > 0 U v CC V. > > k5 0000 (0001 0 0 > o .- 01co (0 rn 5 CC CC L CO LA te 03 U co 0 D >> > > C a) D D > > m D D 7 m U Ln U o rn W = mmmmixmmmUmmU U U Q. o vi co o co of 0.5m CO C0 O] (NI crc7 Ln Lf) o CA �^. Lu co CO m m co co CO co m ° CO CO CO CO O MCO o — @ CO- CO- CO_ Ln V> o co- - J C C C C C C C C C C C C C C C? YYYYYYYYYY Y Y 00000000000000 7 > 7ro co co ro co co no co as co 7 CO C N a) a) a) a) a) a) a) a) a) a) a) a) a) a) U m m Co m m m CO m CO CO CO CO CO CO CO 43 13 O O —O N -- o 1 o . - O - 0 0 —O 0 OI/� Y/ - - o L!) ` _ m 0) co V 4* LL RI o-o _ N 0 � O CD o - o COCV —O o M U – N N 0 0 Im - o -oo 4�1ao CD1111 r2. CO o IX a/ O a C c - o C d N —o v a o 0 V U (g _ N J = CD i i j i it i i 1 o J O u ON O A o N o O Q ` C O co U) N O N N O — O OD N- CO U) C) N O r C CO `C w mped uoie)eda Q U 2.(c/-/72.— Davies, Stephen F (DOA) From: Monty Myers <mmyers@hilcorp.com> Sent: Tuesday,July 22, 2014 1:51 PM To: Davies, Stephen F (DOA) Cc: Jeff Allen;John Serbeck Subject: RE: BC 24 (PTD #214-112) Permit to Drill Application: Questions Steve, Sorry it took me so long to reply. Been in meetings all day today. The shallow gas that is stated on the geoprog should not pose a drilling hazard for drilling the BC#23 or#24. We have drilled through this zone most recently with Saxon 169 on BC#7A and didn't see anything that would raise a red flag. There may be some gas there but it is normal pressured and poses no risk to safety or environment. I included our geologist and reservoir engineer on this email for comment. Do you guys have any concern about the shallow gas, or can you answer Steve's question with more detail? Thanks! 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: Monday, July 21, 2014 5:49 PM To: Monty Myers Subject: BC 24 (PTD #214-112) Permit to Drill Application: Questions Monty, The Geo-Prog on page 42 of the supporting documents for Hilcorp's Permit to Drill application lists"Shallow Gas" as an anticipated formation top in the Sterling Formation at 3016'TVD, which is above Hilcorp's planned surface casing point. Can you tell me what this"Shallow Gas" marker is, and whether or not it constitutes a drilling hazard? Thanks, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If 1 you are an unintended recipient of this e-.„dil, please delete it,without first saving or forty..,ding it, and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 2 Davies, Stephen F (DOA) From: Monty Myers <mmyers@hilcorp.com> Sent: Thursday, September 04, 2014 6:36 AM To: Davies, Stephen F (DOA) Subject: RE: Beaver Creek 24 (PTD# 214-112): Need Revised Directional Survey Attachments: BCU 24 wp5.0 - Proposal Report DRAFT.pdf; BCU 24 wp5.0.txt Here you go Steve. In pdf and digital format. If you need anything else please let me know. Thank you! 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, September 03, 2014 5:58 PM To: Monty Myers Subject: Beaver Creek 24 (PTD # 214-112): Need Revised Directional Survey Monty, Could Hilcorp please provide the latest version of the proposed directional survey data for Beaver Creek 24? Thanks, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 1 Davies, Stephen F (DOA) From: Davies, Stephen F(DOA) Sent: Monday, August 18, 2014 11:51 AM To: 'Monty Myers' Cc: Schwartz, Guy L(DOA) Subject: Revised Permit to Drill Forms: BCU #23 (214-093) and BCU #24 (214-112) Monty, The AOGCC requires actual signatures on all forms, so the signed, revised Permit to Drill forms for BCU 23 and BCU 24 must be either mailed or delivered. Thanks for your help, 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, August 18, 2014 11:47 AM To: Davies, Stephen F (DOA) Cc: Schwartz, Guy L(DOA); Bettis, Patricia K(DOA) Subject: RE: Another well on Saxon 169 - BCU #24(214-112) Steve, Can I email these or would you like me to deliver the paper copies? 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: Monday, August 18, 2014 10:02 AM To: Monty Myers Cc: Schwartz, Guy L (DOA); Bettis, Patricia K(DOA) Subject: RN: Another well on Saxon 169 - BCU #24 (214-112) P.S. The same for BCU #24... From: Davies, Stephen F (DOA) Sent: Monday, August 18, 2014 10:00 AM To: 'Monty Myers' Cc: Schwartz, Guy L(DOA); Bettis, Patricia K (DOA) Subject: RE: Another well on Saxon 169 - BCU #23 (214-093) 1 Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Monday, August 18, 2014 10:02 AM To: Monty Myers (mmyers@hilcorp.com) Cc: Schwartz, Guy L (DOA); Bettis, Patricia K (DOA) Subject: FW: Another well on Saxon 169 - BCU #24 (214-112) P.S. The same for BCU #24... From: Davies, Stephen F (DOA) Sent: Monday, August 18, 2014 10:00 AM To: 'Monty Myers' Cc: Schwartz, Guy L (DOA); Bettis, Patricia K (DOA) Subject: RE: Another well on Saxon 169 - BCU #23 (214-093) Monty, Thanks for your prompt reply. I look at these situations from a "clarity of records" view point: What will be clearest to a reader 10 years from now? AOGCC's Permit to Drill form concisely summarizes all critical information about a planned well. Hilcorp's Sundry Application form states only that the previously approved program is being changed, but it tells nothing about the details of the changes. It's then left to the reader to hunt for those changes in the revised, 70-page BCU 23 Drilling Program—kind of like a technical "Where's Waldo" book. So, please submit a revised Permit to Drill form for BCU 23 with a brief cover letter explaining what changes Hilcorp seeks. Note that Regulation 20 AAC 25.015(a)(1) states that the operator shall "submit and obtain the commission's approval of a new application for a Permit to Drill if the proposed surface location is changed..." (Any change to the surface location necessitates a new Permit to Drill form.) Thanks for your help, 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, August 18, 2014 9:34 AM To: Davies, Stephen F (DOA) Cc: Schwartz, Guy L (DOA) Subject: RE: Another well on Saxon 169 - BCU #23 (214-093) Good morning Steve! I wasn't sure what form I should have submitted. The major changes for BCU 23 is the SHL changed by about 20' from as-staked to as-built. If I need to submit the information on a revised permit to drill form I can certainly get that to you quickly. 1 On the BCU #24,the SHL shifted by approx. 120'from as-staked to as-built and the directional plan was revised quite drastically as well. Original TMD 10808', New TMD 9675', Old TVD 10126', New TVD 9080'. I also updated all the MASP calculations and schematics for both wells. Please let me know if I need to change the form out. Thank you! 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: Monday, August 18, 2014 9:09 AM To: Monty Myers Cc: Schwartz, Guy L (DOA) Subject: RE: Another well on Saxon 169 - BCU #23 (214-093) Monty, Received Hilcorp's Sundry Application for BCU 23, and I notice that this application is essentially an application for a revised Permit to Drill. Just curious as to what's changed besides the wellbore trajectory and why Hilcorp didn't submit a revised Permit to Drill form rather than a Sundry Application. 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: Tuesday, July 01, 2014 1:53 PM To: Davies, Stephen F (DOA) Cc: Schwartz, Guy L (DOA) Subject: Another well on Saxon 169 - BCU #23 Steve, Guy, Attached are the digital surveys for another well behind Saxon 169, called BCU#23. It will be a grassroots well out on pad#3 in Beaver Creek. If you have any questions please let me know! This permit was submitted last Friday, so hopefully you have received it. 2 Our asset team would love to stay in ucaver Creek and drill this well after the curs ,t well we are on, but I don't think I will be able to get approval in time from BLM to do that. Thank you! If you need anything else please give me a shout. Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 3 Davies, Stephen F (DOA) From: Monty Myers <mmyers@hilcorp.com> Sent: Monday, August 18, 2014 11:47 AM To: Davies, Stephen F (DOA) Cc: Schwartz, Guy L(DOA); Bettis, Patricia K(DOA) Subject: RE:Another well on Saxon 169 - BCU #24 (214-112) Steve, Can I email these or would you like me to deliver the paper copies? 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: Monday, August 18, 2014 10:02 AM To: Monty Myers Cc: Schwartz, Guy L(DOA); Bettis, Patricia K (DOA) Subject: FW: Another well on Saxon 169 - BCU #24 (214-112) P.S. The same for BCU#24... From: Davies, Stephen F (DOA) Sent: Monday, August 18, 2014 10:00 AM To: 'Monty Myers' Cc: Schwartz, Guy L (DOA); Bettis, Patricia K(DOA) Subject: RE: Another well on Saxon 169 - BCU #23 (214-093) Monty, Thanks for your prompt reply. I look at these situations from a "clarity of records"view point: What will be clearest to a reader 10 years from now? AOGCC's Permit to Drill form concisely summarizes all critical information about a planned well. Hilcorp's Sundry Application form states only that the previously approved program is being changed, but it tells nothing about the details of the changes. It's then left to the reader to hunt for those changes in the revised, 70-page BCU 23 Drilling Program—kind of like a technical "Where's Waldo" book. So, please submit a revised Permit to Drill form for BCU 23 with a brief cover letter explaining what changes Hilcorp seeks. Note that Regulation 20 AAC 25.015(a)(1)states that the operator shall "submit and obtain the commission's approval of a new application for a Permit to Drill if the proposed surface location is changed..." (Any change to the surface location necessitates a new Permit to Drill form.) Thanks for your help, 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 1 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, August 18, 2014 9:34 AM To: Davies, Stephen F (DOA) Cc: Schwartz, Guy L(DOA) Subject: RE: Another well on Saxon 169 - BCU #23 (214-093) Good morning Steve! I wasn't sure what form I should have submitted. The major changes for BCU 23 is the SHL changed by about 20'from as-staked to as-built. If I need to submit the information on a revised permit to drill form I can certainly get that to you quickly. On the BCU#24,the SHL shifted by approx. 120'from as-staked to as-built and the directional plan was revised quite drastically as well. Original TMD 10808', New TMD 9675', Old TVD 10126', New TVD 9080'. I also updated all the MASP calculations and schematics for both wells. Please let me know if I need to change the form out. Thank you! 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: Monday, August 18, 2014 9:09 AM To: Monty Myers Cc: Schwartz, Guy L(DOA) Subject: RE: Another well on Saxon 169 - BCU #23 (214-093) Monty, Received Hilcorp's Sundry Application for BCU 23, and I notice that this application is essentially an application for a revised Permit to Drill. Just curious as to what's changed besides the wellbore trajectory and why Hilcorp didn't submit a revised Permit to Drill form rather than a Sundry Application. 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. 2 From: Monty Myers [mailto:mmyers©hilcorp.com] Sent: Tuesday, July 01, 2014 1:53 PM To: Davies, Stephen F (DOA) Cc: Schwartz, Guy L(DOA) Subject: Another well on Saxon 169 - BCU #23 Steve, Guy, Attached are the digital surveys for another well behind Saxon 169, called BCU#23. It will be a grassroots well out on pad#3 in Beaver Creek. If you have any questions please let me know!This permit was submitted last Friday, so hopefully you have received it. Our asset team would love to stay in Beaver Creek and drill this well after the current well we are on, but I don't think I will be able to get approval in time from BLM to do that. Thank you! If you need anything else please give me a shout. Monty M Myers Drilling Engineer Hilcorp Alaska Office: 907.777.8431 Cell: 907.538.1168 3 TRANSMITTAL LETTER CHECKLIST WELL NAME: ! z E (") lS'eci PTD: 21L7 /1Z—' /Development Service Exploratory Stratigraphic Test Non-Conventional FIELD: Com_ POOL: 411, 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 Well Lo ,n also required for this well: gg g Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 4/2014 [11 LI To ao) a co N I' p O sa co - - 7 N c • Q Q W m a c O 0 0 ai o d . W. o W ma 0 O O 7 O -O -O 0, V n m a a E E a E E 0 m e `o_ w 0) 0. a a) N N > O 0 X O Oa �, o �, l0 U C 0 _o — 3 co 0 a a cp .c o o) 0 o co c, -c, -0 co a) S w' a . gin' d N c a) o 3 �. Y 3 0 °. a > CO • d 0 N0 ami. > v` 0) 0) w - 1_. to a 0, y' 0 3 o o0 CO 0 0. o, @ N .0 o D o a N. a 0, •y E - o w M E u, E _ aO - c o w E 2 a m. i ( w o w o. , c, U, c 7 J ?i 15 c @ dO OH . >. c,o. o.a • o.a o.al LO 0 iai a) • , co 0 _ a co c coo > aa, .o m, v. r m. m; CO' r �. �. a C w co J 0. 0 ay M. • w U 3. 'y a). �`'>. 'y. y. CO. 'U 0 >• 00 CD o m 3 N rn aa) o , � ° 7.4.5_ . a N o C L o@ CO m W 0 Y o a 0 N _ .3 U y m p .y . .� -0 in m a)CO LL w a0 C C a -• 0) 0) a) , ay 2. u) c d c v 3. MP t o • C a'' a N ? o U C. •,' Y. �. �. 3 C _C 0. - 00• a). U =. O 0) 0 N 3 a' N d � € ,t U, 0) 0- O: .. 00 w - €�. L: II. 0 0, 'p: � � "6 7 p Z a) N C �. as co �. a L N £, 0, w. c a' C C C, U 0. N a) V) o Q 0 0 X 't E U c`o. O, X X X u1' (C' N ° 6 .4(..• ; c w t (0 • co (O O `o i. m 0. (o• (0• Q• N• N• W CO H w O cm (O ((i (oi. co Ck (9• a. (n• g• co �• _• M. O d m °) O O .N w > p a) Er U) N CA N u) u) CA (/) Cl) Cl) Cl) Cl) u) U) Col) u) N V)• CO CII V1• CO CO CO N• N• CO N• < 0 a) a) a) 0 a) a) a) a) a) a) a) Q Q Q < 0 0. a) a) a), a). a), <C a), a), a). 0 a), a) a), o, Q, a), a), <, < Q a Z >- >- r >- Y >- z z Z z >- >- >- } } } }, z } } } } } } }, z, z, >- }, z, z z ? ~N p 0 \. . 0co T 6- fp _ C . U co, o c '':_T -ecN 0 N E E 3 - E a) LI2". , aE 7 o ,_ o o a), E U Q co o 0 ° E -c-n.' 3, 1 , o co 0 0 co c o CO o a) w p ami. E, a) @ Q '00 Ca N. u) co N O. .0.. O. o N. fl' O c > c lL t a _ U V �, °� a) O 7 7co 17 � N a @ 11 itiiIi ON 0 E N' -.2"- 0,.? ' O M "O 0 7 ° CO N s 0) i Z !n co ° 3 o u) c 0, 'C c ur a .� LO ° Q u) CO' 0 U V 0 C "0 0 a) C 9 t0 N 0. •_ D O c, 0 m, 0 0 0) 0' d - c C N C' d' 0 a' E E -o C C E .- y6 N O c'`) C c. .y > i C. 4 0. CSS. w a. O .c a) O: N' t a C c W O 0 0 ° O e- 02 c u) 3' o v w'. @' d U c, CD N O 0 u y. T 1 C a) w w c ) c o o E N o a Q c a) 0) U a 0, c o. a) a �. 3 >' CO 4' g m Q a 0 a) 0 C o > > ° •0 (a .m o Y m ° o o; a). o' E m 'co co Q a- a N >, a CB o a) CO m -I a) K a c c z m a _c t m d o u) -0 m c. - a) aa)) o 2 ` a) rn 0, a) a n i t m o " 3 ° EU U J c y RS `° ° a m -3 •3 a) E v, �, .6 3 m Mo �. a) °. N, ° �. �, o w o O < a D C C 0 -0 • > 0 _ •• O .- U U. :.' 0 0 I. 0• 0• u/. ...+ a .n j. Cd O. 3, . t. U o Y.. 0 c ' a 'O >, 0 p, '0.. '0 O CO o c .0+' O O c „,Cr T 0 VN. o 0) C 'O. ° ul, Z N. a co -° 0 O m o a) 0 E o o' o 0' E m 0 E .c o m a ., co' c, Q y a o a) a`) O. a c c a°i; °' a °' :? Y. ° �. �. E U N. y c 0, v,. o �) J, r a E N a a o CD a u) u) a :E a ° rn (o' o 3 o. �, c: t 'o U m E o o ca o a co w o .c m rn m (a m. ca, cli a . 0 >l . 2. !_ , it a W •0 '0 '0 U N C m -0 _0 _0 -30 t N c i) 7 N N > 2) N. L N N a .=' ul 0 V; O 00 �� C �p 'O E I a 0 a; 4) <o o ' c c U c ° ° o y . 3' p 0 c o o m c. 0, c, c. O a) E a) o 3 0 a) o, '� o o U co ai 0 -o 2' o o ° ) (a o c F- U w c U �; @ o `o ° U o c U a). o o �' COO •o, CO vi, 4. E' 3, N co�' - J 0 o O O O .V .� N N a ° N a U -0 0' > > 3'• c 0• N. 0. a) c) W, W Y, Y' a) -c G E. J = y 2 •E a) a) )) D -0 a s a) i) 0 a) 3 o o m 2 2' co v co v `a = O O -c ° a m a) coo, a; 0 o a U@aJn � � � (nw00aaUaaz 0cn0C� U; U; ¢ r-, a, = om' m, 05 ,, 2 a0 (0,, (o, O, LU a co - N M d' l() CO N W 0) 0 e- N M 7 1() (O h CO C) O e- N M '7 CO CO h. CO 0) = E e- N co CO to N- to O) e- e- . . . . . e- e- e- N N N N N N N N N N C'7 Ch M M M M M M M M i_ VO _.... _. _..___-_.._. __ __. __..___ ---7- U F_ v i a m w o w .2 O0 C 0.1 o CO v co o 0 v CNI o(•Nil Im- LLIa coC rn N•E 0 J (Ni • E 0 >' CD o J zf I•E d 0 E d v) ° 0. 0 0 W 0 E a w rn a J o a I- Q a W a C ( a 7,4 ,,i 1%%%•a THE STATE A.�'_e cis �� / 1. 333 West Seventh Avenue ve CTO\ I R\OR 5,]A\ PAR\LLL Anchorage Alaska 99501 3572 Monty Mack Myers Drilling Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Beaver Creek Field, Beluga Gas Pool, Beaver Creek#24 Hilcorp Alaska, LLC Permit No: 214-112 Surface Location: 1246' FNL, 1656' FWL, SEC. 34, T7N, R10W, SM, AK Bottomhole Location: 2361' FSL, 1539' FEL, SEC. 34, T7N, RIOW, SM, AK Dear Mr. Myers: Enclosed is the approved application for permit to drill the above referenced development 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, i' -2117c Cathy . Foerster Chair DATED this?day of July, 2014. RECEIVED STATE OF ALASKA AL A OIL AND GAS CONSERVATION COMN, )N JUL 15 2014 PERMIT TO DRILL ae 20 AAC 25.005 AOGCC la.Type of Work: lb.Proposed Well Class: Development-Oil ❑ Service- Winj ❑ Single Zone Q - lc.Specify if well is proposed for: Drill ❑✓ • Lateral ❑ Stratigraphic Test ❑ Development-Gas E• Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal 0 Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket 0 Single Well ❑ 11 Well Name and Number: Hilcorp Alaska,LLC Bond No. 022035244 • Beaver Creek#24 • 3.Address: 6 Proposed Depth: 12 Field/Pool(s): 3800 Centerpoint Drive,Suite 1400,Anchorage AK 99503 MD: 10,808' TVD: 10,126' Beaver Creek Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number). Beluga Gas Surface. 1246'FNL, 1656'FWL,Sec 34,T7N,R1 OW,SM,AK ' A028083 • Top of Productive Horizon: 8.Land Use Permit. 13.Approximate Spud Date. 2102'FNL,2559'FEL,Sec 34,T7N,R10W,SM,AK NA 8/21/2014 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property' 2361'FSL,1539'FEL,Sec 34,T7N,R1OW,SM,AK 1920 acres(A028083) ,3f 2569-Fal mt"�2 4./f 4b.Location of Well(State Base Plane Coordinates-NAD 27)• 10.KB Elevation above MSL: 179.2 feet 15.Distance to Nearest Well Open Surface: x-317473 83 • y-2433936.29 • Zone-4 GL Elevation above MSL: - 160.6 feet to Same Pool: 1,200' 16.Deviated wells: Kickoff depth: 2,000 feet • 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) d 7•2q-/7 Maximum Hole Angle: 31 degrees . Downhole.2psi3 03 Surface: 44grpsi Z SQ L e 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Cond 16" 109 X-56 Weld 80' Surf. Surf 80' 80' Driven 12-1/14" 9-5/8" 40 L-80 BTC 3500' Surf. Surf. 3,500' • 3,402' • 305.3bb1/1713.9ft3 8-1/2" 5-1/2" 17 P-110 DWC/C HT 10,808' Surf. Surf 10,808' 10,126' 427.6bb1/2400.8ft3 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20 Attachments: Property Plat Q BOP Sketch Q Drilling Program ❑✓ Time v.Depth Plot Q Shallow Hazard Analysis❑ Diverter Sketch Q Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25 050 requirements 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Monty Mack Myers Email nlRlyerS(C7hiICOrp.COM Printed Name Monty Mack Myers Title Drilling Engineer Signature Phone (907)777-8431 Date 7/15/2014 Commission Use Only Permit to Drill / // API Number: �q /� Permit Approval See cover letter for other Number: �/ �[ !� 50-/� � }�/ C��Date: 3br�y requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: Ld Other: LJ , p Samples req'd: Yes❑ No ET Mud log req'd:Yes❑ No 100 V rs` 6,)f) J c I ---7;71---- HZS measures: Yes❑ No12/ Directional svy req'd•Yes lig No❑ i Spacing exception req'd: Yes❑ No[r Inclination-only svy req'd:Yes❑ No Hi- -- j4 1-.7 . / APPROVED BY Approved by: 1 COMMISSIONER THE COMMISSION Date. 7-3D-7 7. 1 , t Submit Form and Form 10-401(Revi+ltd 10/2012) Thit the of a royal 20 AAC 25.005(g)) ttachments in Duplicate ORIGINML date �, -' 7z/. RI/ Monty Myers Hilcorp Alaska, LLC Drilling Engineer P.O. Box 244027 Anchorage, AK 99524-4027 Tel 907 777 8431 Email mmyers@hilcorp.com II ileorp Alaska,LLC July 14, 2014 RECEIVED Commissioner JUL 15 2014 Alaska Oil & Gas Conservation Commission AOGCC 333 W. 7th Avenue Anchorage, Alaska 99501 Re: Beaver Creek (BCU)#24 Dear Commissioner, Beaver Creek#24 is a south easterly step-out appraisal well of the lower and middle Beluga gas sands on the eastern flank of the field between the BCU 13 and BCU 6 wells.The base plan is a 10,808' "S-turn"wellbore with a shallow kickoff around 2000', building to a tangent of 31 deg,then dropping back to vertical at 8,459' MD. Drilling operations are expected to commence approximately August 21st, 2014. The Saxon Rig#169 will be used to drill the wellbore then run casing and cement. Surface casing will be run to 3,500' MD/3,402'TVD and cemented to surface to ensure protection of any shallow freshwater resources. Cement returns to surface will confirm TOC at surface. If cement returns to surface are not observed, a Temp log will be run between 6—18 hrs after CIP to determine TOC. Necessary remedial action will then be discussed with AOGCC and BLM authorities. All waste& mud generated during drilling and completion operations will be hauled to the Kenai Gas Field G&I facility for disposal/beneficial reuse depending on test results. General sequence of operations: 1. MOB Saxon Rig# 169 to well site 2. N/U 21-1/4"x 2M diverter. 3. Drill 12-1/4" hole to 3500' MD. Run and cmt 9-5/8" surface casing. 4. N/D diverter, N/U &test 11"x 5M T3-Energy BOP. 5. Drill 8-1/2" hole section to 10,808' MD. Perform Wiper trip. 6. POOH laying down drill pipe. 7. Run and cmt 5-1/2" production casing . 8. N/D BOP, N/U temp abandonment cap, RDMO. Hilcorp Alaska, LLC Page 1 of 2 Monty Myers Hilcorp Alaska, LLC Drilling Engineer P.O. Box 244027 Anchorage, AK 99524-4027 Tel 907 777 8431 Email mmyers@hilcorp.com Ifilrorr Al,i ka,LL C RECEIVED Reservoir Evaluation Plan: 1. Surface hole:GR+Res LWD. ' :JUL 1 5 LU 14 2. Production Hole: GR+Res+Den/Neu LWD. 3. Mud loggers from surface casing point to TD. ' AOGCC If you have any questions, please don't hesitate to contact myself at 777-8431 or Paul Mazzolini at 777-8369. 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 2 of 2 Hilcorp Alaska, LLC Beaver Creek #24 Drilling Program Beaver Creek Field -- ro d by: M• My Version 0 July 10th, 2014 Beaver Creek#24 Drilling Procedure Hilcorp Energy Company Contents 1.0 Well Summary 2 2.0 Management of Change Information 3 3.0 Tubular Program• 4 4.0 Drill Pipe Information: 4 5.0 Internal Reporting Requirements 5 6.0 Planned Wellbore Schematic 6 7.0 Drilling/Completion Summary 7 8.0 Mandatory Regulatory Compliance/Notifications 8 9.0 R/U and Preparatory Work 11 10.0 N/U 21-1/4"2M Diverter 12 11.0 Drill 12-1/4" Hole Section 15 12.0 Run 9-5/8" Surface Casing 20 13.0 Cement 9-5/8" Surface Casing 23 14.0 BOP N/U and Test 26 15.0 Drill 8-1/2"Hole Section 27 16.0 Run 5-1/2"Production Casing 32 17.0 Cement 5-1/2"Production Casing 35 18.0 RDMO 38 19.0 BOP Schematic 39 20.0 Wellhead Schematic 40 21.0 Days Vs Depth 41 22.0 Geo-Prog 42 23.0 Anticipated Drilling Hazards 43 24.0 Saxon Rig 169 Layout 45 25.0 FIT Procedure 46 26.0 Choke Manifold Schematic 47 27.0 Casing Design Information 48 28.0 8-1/2" Hole Section MASP 49 29.0 Spider Plot(NAD 27)(Governmental Sections) 50 30.0 Surface Plat(As Staked)(NAD 27) 51 31.0 Surface Plat(As Staked)(NAD 83) 52 32.0 Directional Survey 53 Beaver #2 Drilling Procedure Rev 0 Hilcorp Energy Company 1.0 Well Summary Well Beaver Creek#24 • Pad&Old Well Designation Beaver Creek#24 is a grass roots well on BCU Pad#3 Planned Completion Type 5-1/2"Production tubing Target Reservoir(s) Beluga • Planned Well TD,MD/TVD '10,808 MD/ 10,126' TVD ' PBTD,MD/TVD 10,700' MD/ 10,018' TVD Surface Location(Governmental) 1246' FNL, 1656' FWL, Sec 34, T7N,R1OW, SM,AK ' Surface Location(NAD 27) X=317473.83,Y=2433936.29 ' Surface Location(NAD 83) X=1457494.99,Y=2433697.18 Top of Productive Horizon (Governmental) 2102' FNL,2559' FEL, Sec 34,T7N,RIOW, SM,AK TPH Location(NAD 27) X=318521.33,Y=2433072.37 TPH Location(NAD 83) X=1458542.51,Y=2432833.20 BHL(Governmental) 2361'FSL, 1539'FEL, Sec 34,T7N,R1OW, SM,AK BHL(NAD 27) X=319530.2,Y=2432240.3 BHL(NAD 83) X=1459551.39,Y=2432001.08 AFE Number 1412278D AFE Drilling Days 5 MOB,22 DRLG AFE Completion Days AFE Drilling Amount $4,834,020 AFE Completion Amount $300,000 Maximum Anticipated Pressure (Surface) 1462 psi(Drilling) Maximum Anticipated Pressure • (Downhole/Reservoir) 2592 psi Work String 4-1/2" 16.6#S-135 CDS-40(Saxon Owned String) RKB—GL 179.2'(160.6+ 18.6) • Ground Elevation 160.6' • BOP Equipment 11"5M T3-Energy Annular BOP 11"5M T3-Energy Double Ram 11" 5M T3-Energy Single Ram Page 2 Version 0 July, 2014 Beaver Creek#24 Drilling Procedure Rev 0 Hilcorp Energy Company 2.0 Management of Change Information Hilcorp Alaska; LLC Hilcorp nrrgy Company Changes to Approved Permit to Drill Date: July 10,2014 Subject: Changes to Approved Permit to Drill for Beaver Creek#24 File#: Beaver Creek#24 Drilling Program Any modifications to the Drilling&Completion Program will be documented and approved below. Changes to an approved APD will be the AOGCC&BLM. JjV/ _„.e> 7 Z'. is Date Procedure Change Approved Approved By By Approval: Drilling Manager Date Prepared: Drilling Engineer Date Page 3 Version 0 July, 2014 Beaver Creek#24 Drilling Procedure Rev 0 Hilcorp Energy Company 3.0 Tubular Program: Hole OD(in) ID(in) Drift Conn de Conn Burst Collapse Tension Section (in) OD(in) (#/ft) (psi) (psi) (k-lbs) Cond 16" 15" - - 109 X-56 Weld 12-1/4" 9-5/8" 8.835" 8.679" 10.625" 40 L-80 BTC 5750 3090 916 8-1/2" 5-1/2" 4.892 4.767 6.050 17 P-110 DWC/CHT 10640 7480 546 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) All -1-1/2" 3.826 2.6875" 5.25" 16.6 S-135 CDS40 17.693 16.769 468k All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery to TSA in Fairbanks). Page 4 Version 0 July,2014 Beaver Creek#24 Drilling Procedure Rev 0 Hilcorp E Company 5.0 Internal Reporting Requirements 5.1 Fill out daily drilling report and cost report on Wellez. • Report covers operations from 6am to 6am • Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left of the data entry area—this will not save the data entered,and will navigate to another data entry tab. • Ensure time entry adds up to 24 hours total. • Try to capture any out of scope work as NPT. This helps later on when we pull end of well reports. 5.2 Afternoon Updates • Submit a short operations update each work day to pmazzolini@hilcorp.com , lkeller@hilcorp.com mmyers@hilcorp.com and_jbarrett n,hilcorp.com 5.3 Intranet Home Page Morning Update • Submit a short operations update each morning by 7am on the company intranet homepage. On weekend and holidays, ensure to have this update in before 5am. Each rig will be assigned a username to login with. 5.4 EHS Incident Reporting • Notify EHS field coordinator. 1. This could be one of(3) individuals as they rotate around. Know who your EHS field coordinator is at all times,don't wait until an emergency to have to call around and figure it out!!!! a. John Coston: 0: (907)777-6726 C: (907)227-3189 b. Mark Tornai: 0: (907)283-1372 C: (907)748-3299 c. Thad Eby: 0: (907)777-8317 C: (907)602-5178 2. Spills: Kate Kaufman: 0:907-777-8329 C:907-244-8292 • Notify Drlg Manager 1. Paul Mazzolini: 0: 907-777-8369 C: 907-317-1275 • Submit Hilcorp Incident report to contacts above within 24 hrs 5.5 Casing Tally • Send final"As-Run"Casing tally to mmyers@hilcorp.com and jbarrettn,hilcorp.com 5.6 Casing and Cmt report • Send casing and cement report for each string of casing to mmyers a,hilcorp.com and ibarrettAhilcorp.com Page 5 Version 0 July, 2014 Beaver Creek#24 Drilling Procedure Rev 0 Hilcorp Enmgy Company 6.0 Planned Wellbore Schematic Beaver Creek Unit PROPOSED WellBCU#24 PTD: 000-000 API: 50-000-00000-00 CASING DETAIL I L ' 5de Type Wt Grade Conn. ID Top Btrr Mud lb' `- Weight Conductor 18" —Drrven 109 X-56 Weld 16" Surf BD' to Set Depth 9-5/5` Surf.Csg 40 L-80 BTC 8.835" Surf 3500' 5.6 ppg 5-1/2' Prod Csg 17 P-110 <7 C/C 4.692" Surf 10,806' 9.0 ppg 4tow 1 Drilling Info • Hole Section Casing M W Workitring 12-1/4'" 9-5/8` 8.8 ppg 4-1/2k 4 8-1/2" 5-1/2" 9.0-9.5 ppg 4-1/2" JEWELRYDETAIL No. Depth ID OD Item 1 3000' 4.892" 8.5" Baker Swed Packer 8-1/2" Hole SN•��a. • 1 5-1/2" P3rD=10.'50'!P81112=10,01S' • TD=10.551'lTVD=10.126' Page 6 Version 0 July, 2014 Beaver Creek#24 Drilling Procedure Rev 0 Hilcorp I nergy Company 7.0 Drilling / Completion Summary Beaver Creek#24 is a south easterly step-out appraisal well of the lower and middle Beluga gas sands on the eastern flank of the field between the BCU 13 and BCU 6 wells.The base plan is a 10,808' "S-turn" wellbore with a shallow kickoff around 2000',building to a tangent of 31 deg,then dropping back to vertical at 8,459' MD. Drilling operations are expected to commence approximately August 21 s`,2014. The Saxon Rig# 169 will be used to drill the wellbore then run casing and cement. Surface casing will be run to 3,500' MD/3,402' TVD and cemented to surface to ensure protection of any shallow freshwater resources. Cement returns to surface will confirm TOC at surface. If cmt returns to surface are not observed,a Temp log will be run between 6— 18 hrs after CIP to determine TOC. Necessary remedial action will then be discussed with AOGCC and BLM authorities. All waste&mud generated during drilling and completion operations will be hauled to the Kenai Gas Field G&I facility for disposal/beneficial reuse depending on test results. General sequence of operations: 1. MOB Saxon Rig# 169 to well site 2. N/U 21-1/4"x 2M diverter. 3. Drill 12-1/4"hole to 3500' MD. Run and cmt 9-5/8" surface casing. 4. N/D diverter,N/U &test 11"x 5M T3-Energy BOP. 5. Drill 8-1/2"hole section to 10,808' MD. Perform Wiper trip. 6. POOH laying down drill pipe. • 7. Run and cmt 5-1/2"production casing . 8. N/D BOP,N/U temp abandonment cap, RDMO. Reservoir Evaluation Plan: • 1. Surface hole: GR+Res LWD. 2. Production Hole: GR+Res+Den/Neu LWD. 3. Mud loggers from surface casing point to TD. _ Page 7 Version 0 July, 2014 Beaver Creek#24 111 Drilling Procedure Rev 0 Hilcorp Bump Company 8.0 Mandatory Regulatory Compliance / Notifications Regulatory Compliance Ensure that our drilling and completion operations comply with the below AOGCC regulations. If additional clarity or guidance is required on how to comply with a specific regulation,do not hesitate to contact the Anchorage Drilling Team. • BOPs shall be tested at(2)week intervals during the drilling of Beaver Creek#24. Ensure to provide AOGCC 24 hrs notice prior to testing BOPs. • The initial test of BOP equipment will be to 250/4000 psi & subsequent tests of the BOP equipment will be to 250/4000 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 approved drilling permit and BLM sundry are posted on the rig floor and in Co Man office. Regulation Variance Requests: • Onshore Oil and Gas Order No. 1, Section III. D. 3. C. o Hilcorp requests approval to install a 3-1/8" 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. o Hilcorprequests approval to utilize flexible choke and kill lines in lieu of hard piping. ,,c1� q pP p•P� g• Page 8 Version 0 July,2014 Beaver Creek#24 Drilling Procedure Rev 0 Hilcorp Energy Company Summary of BOP Equipment and Test Requirements Hole Section Equipment Test Pressure(psi) 12-1/4" • 21-1/4"x 2M Hydril MSP diverter Function Test Only • 11"x 5M T3-Energy(Model 7082)Annular BOP • 11"x 5M T3-Energy Double Ram Initial Test:250/4000 ' o Blind ram in btm cavity (Annular 2500 psi) • Mud cross 8-1/2" • 11"x 5M T-3 Energy Single Ram • 3-1/8"5M Choke Line Subsequent Tests: • 2-1/16"x 5M Kill line 250/4000 • 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 and Sundry. Page 9 Version 0 July,2014 Beaver Creek#24 Drilling Procedure Rev 0 Hilcorp oma Comwnr Regulatory Contact Information: AOGCC Jim Regg/AOGCC Inspector/(0): 907-793-1236/Email:jim.regg n,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@blm.gov Page 10 Version 0 July,2014 Beaver Creek#24 Drilling Procedure Rev 0 Hilcorp Elmo Company 9.0 R/U and Preparatory Work 9.1 Set 16" conductor at 80' below ground level. 9.2 Dig out and set impermeable cellar. 9.3 Install Seaboard slip-on 16-3/4" 3M "A" section. Ensure to orient wellhead so that tree will line up with flowline later. 9.4 Level pad and ensure enough room for layout of rig footprint and R/U. 9.5 Layout Herculite on pad to extend beyond footprint of rig. 9.6 R/U Saxon Rig# 169, spot service company shacks, spot& R/U company man&toolpusher offices. 9.7 Mud loggers not required on surface hole section. 9.8 After rig equipment has been spotted, R/U handi-berm containment system around footprint of rig. 9.9 Mix mud for 12-1/4" hole section. 9.10 Set test plug in wellhead prior to N/U diverter to ensure nothing can fall into the wellbore if it is accidentally dropped. 9.11 Install 5-1/2" liners in mud pumps. • TSM 1000 mud pumps are rated at 3633 psi (85%)/333 gpm (100%) with 5-1/2" liners. Page 11 Version 0 July,2014 Beaver Creek#24 Drilling Procedure Rev 0 Hilcorp Energy Company 10.0 N/U 21-1/4" 2M Diverter 10.1 N/U 21-1/4"Hydril MSP 2M diverter System. • N/U 16-3/4" 3M x 21-1/4" 2M DSA (Hilcorp)on 16-3/4" 3M wellhead. • N/U 21-1/4" diverter"T". • Knife gate, 16" diverter line. • Ensure diverter R/U complies with AOGCC reg 20.AAC.25.035(C). 10.2 Function test diverter. Ensure that the knife gate and annular are operated on the same circuit so that knife gate opens prior to annular closure. � t/�/: -re p�10.3 Ensure to set up a clearly marked"warning zone" is established on each side and ahead of the vent line tip. "Warning Zone"must include: • A prohibition on vehicle parking • A prohibition on ignition sources or running equipment • A prohibition on staged equipment or materials • Restriction of traffic to essential foot or vehicle traffic only. 10.4 Set 15.375" ID wearbushing in wellhead. Page 12 Version 0 July,2014 Beaver Creek#24 Drilling Procedure Rev 0 Hilcorp 10.5 Ri: and Diverter Line Orientation on Beaver Creek 3 sad: wfY 4' 0334Z 4 • V Beaver Creek Unit t- .=00 Met I, Pad 3 Feet W ac.te3Q. G _4 I oo Page 13 Version 0 July,2014 Beaver Creek#24 Drilling Procedure Rev 0 Hilcorp Energy Company 10.6 Diverter Schematic mom0111110 1101(./ ( I111f lI11 «l til lit ll Annular Preventer 3ytiraltslSP 21-'h" 2M Ii _ IlI , \ Knife Gate ItI III 111111 III ta- 1E ' Diverter line Diverter Tee,21-%"x 21-1"x 2M w/16"ANSI 150 outlet • 010146 - 111111111111 III 16-% 3M x 21-1/4"2M©SA �N mem 11 tine. Seaboard 16-Y4"3M tr Casing head Assy 6" Page 14 Version 0 July, 2014 Beaver Creek#24 II Drilling Procedure Rev 0 Hilcorp Emmy Company 11.0 Drill 12-1/4" Hole Section 11.1 P/U 12-1/4" directional drilling assy: • Ensure BHA components have been inspected previously. • Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. • Ensure TF offset is measured accurately and entered correctly into the MWD software. • Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. • Workstring will be 4.5" 16.6# S-135 CDS40 11.2 12-1/4"BHA (GR and Res LWD are included in below BHA): Page 15 Version 0 July,2014 Beaver Creek#24 II Drilling Procedure Rev 0 Hilcorp Energy Company COMPONENT DATA ItemOD ID Gauge Weight Top Length Cumulative Description ber # Connection (in) (in) (in) (Ibpf) (ft) Length (ft) ME HDBS-OHC1GRC Milltooth 12.200 3.000 12.250 374.30 P 6-578'REG 1.20 1.20 © 8"SperryDri Lobe 415-5.3 stg _ 8.000 5.000 121-08 B 6-518'REG 28.99 30.19 Ell Stabilizer _ 11 DO _--- ® Integral Blade Stabilizer B.0D0 2.813 12.125 150 12 B 6-5/8'REG 5.00 36.19 © 8"DM Collar(Directional; 8.000 3.500 14740 B 6-518-REG 9.20 45.39 ® 9'DGR Collar (Ga---a) B.000 1.920 142.70 B 6-518'REG 4.55 49 94 6 8'EWR-P4 Collar(Resistively! 8.000 2.000 151.00 B 6-518-REG 12.19 62.13 a B"HCIM Collar{Processor) 8.000 1.920 149.90 B 6-58'REG 4.97 67.10 IIE 13-TM-HOC(Pulsed 8.150 4.000 145 20 B 6.5.8'REG 15 77 82.87 9 Orienting Sub UBHO 8.000 3.000 14722 8 6-5.8'REG 3.50 85.37 ® Non Mao Flex Dnil Col a' 8.000 3.000 14722 B 6-5.8'REG 3000 116.37 IBM Non Meg Flex Drill Colar 8.000 3.00G 147.22 B 6-5.8'REG 30.00 145.37 ® X-0 6-5B Reg Pin X 4-1 it IF Box 8.000 2.813 150.12 B 4-1.2"IF 3.50 149.87 ® 8 Joints 5"HWDP 5.000 3.000 -2.30 240.00 380 87 ® 'Weatherford 6-114-Hyd Jar 6.250 2.250 91.Cl 8:-1:2'IF 30.00 419 37 ® 19 Joints 5"HWDP 5.000 3.000 49.30 570.00 989.87 .., .,,.. 989 87 BIT DATA Bit Number Nozzles ix12,3x18 Bit Size (in) : 12.250 TFA (in2) :0.8550 Manufacturer : HOBS Dull Grade In . Model Dull Grade Out .• Serial Number .• MOTOR DATA Motor Number : 2 Bend (deg) : 1.15 OD (inl : 8.000 Nozzles (32nd) : 0.0 Manufacturer : Sperry Drilling Avg Diff Press .• Model : SperryDrill Cumul Cir Hrs • Serial Number . Page 16 Version 0 July, 2014 Beaver Creek#24 fl Drilling Procedure Rev 0 Hilcorp Energy Company 11.3 Primary Bit: 12-1/4" (311mm) CitiC1GRC PRODUCT SPECIFICATIONS IADC Code 117W Total Tooth Count 67 16. Gage Row Tooth Count Journal Angle 33' Offset(1 let 6 Jet Nozzle Types Standard 83244 Extended 302447 Center Jet (If Center Jetted)501813 T.J.Connection 6-5/8"(API Reg.) Recommended Make-Up Torque* 28000,32000 Ft*lbs. Bit Weight(Boxed) 250 Lbs.(113 Kg.) Bit Breaker (Mat.1,11..egacy0) 515351306463 PRODUCT FEATURES \ • New patented Diamond**,Claw R tooth bit design. • Tungsten carbide'surf inserts in gage teeth for added gage protection. • Newly formulated.proprietary hardfacing on cutting structure and 11[0 'Iii*Vr-t,4110 gage maximizes carbide and diamond volume for ultimate wear 0 resistance. • High-speed bearing designed for high rpm and high-energy applications. • Innovative mechanical pressure compensating system provides reliable pressure equalization and relief for maximum bearing and seal life. • Raised tungsten carbide inserts and proprietary hardfacing provides maximum arm protection in abrasive and directional applications while minimizing drill string torque. • QuadPackt Plus Series incorporates its successful"longevity" ' features and patented engineered hydraulics system for optimal cleaning efficiency. • Center jet feature to prevent bit balling problems Material#622394 .cateuiaiims based on recommentiations from API and tool-joint manufacturers. C 2012 Halliburton,All rights reserved.Sales of Halliburton products and services will be in accord solely with the terms and conditions contained in the contract between Halliburton and the customer that is applicable to the sale. Page 17 Version 0 July, 2014 Beaver Creek#24 Drilling Procedure Rev 0 Hilcorp Energy Company 11.4 4-1/2" Workstring& HWDP will come from Saxon. Jars will come from Weatherford. 11.5 Begin drilling out from 16"conductor at reduced flow rates to avoid broaching the conductor. • 11.6 Drill 12-1/4" hole section to 3,500' MD/3,402' TVD. Confirm this setting depth with the geologist and Drilling Engineer while drilling the well. • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • Pump at 500 - 550 gpm. Ensure shaker screens are set up to handle this flowrate. • Utilize Inlet experience to drill through coal seams efficiently. Coal seam log will be • provided by Hilcorp Geo team. • Keep swab and surge pressures low when tripping. • Make wiper trips every 500' or every couple days unless hole conditions dictate otherwise. • Ensure shale shakers are functioning properly. Check for holes in screens on connections. • Adjust MW as necessary to maintain hole stability. • TD the hole section in a good shale between 3400' MD and 3600' MD. • • Take MWD surveys every stand drilled(60' intervals). • 11.7 12-1/4" hole mud program summary: • Weighting material to be used for the hole section will be barite. Additional barite will be on ✓ • location to weight up the active system (1) ppg above highest anticipated MW. We will start with a simple gel+ FW spud mud at 8.8 ppg. Pason PVT will be used throughout the drilling and completion phase. Remote monitoring stations will be available at the driller's console, Co Man office, Toolpusher office, and mud loggers office. System Type: 8.8—9.5 ppg Pre-Hydrated Aquagel/freshwater spud mud Properties: Depths Density Viscosity Plastic Viscosity Yield Point API FL pH 80-3500' 8.8—9.5 85-150 20-40 25-45 <10 8.5-9.0 Page 18 Version 0 July, 2014 Beaver Creek#24 II Drilling Procedure Rev 0 Hilcorp E CernianY System Formulation: Aquagel + FW spud mud Product Concentration Fresh Water 0.905 bbl soda Ash 0.5 ppb AQUAGEL 12-15 ppb caustic soda 0.1 ppb (9 pH) BARAZAN D+ as needed BAROID 41 as required for weight PAC-L/DEXTRID LT if required for<12 FL ALDACIDE G 0.1 ppb X-TEND II 0.02 ppb 11.8 At TD; pump sweeps, CBU,and pull a wiper trip back to the 16" conductor shoe. 11.9 TOH with the drilling assy, handle BHA as appropriate. 11.10 No open hole logs are planned for the 12-1/4" hole section. / I Page 19 Version 0 July,2014 Beaver Creek #24 Drilling Procedure Rev 0 Hilcorp I.nergy Company 12.0 Run 9-5/8" Surface Casing 12.1 R/U and pull 15.375"wearbushing. 12.2 R/U Weatherford 9-5/8" casing running equipment. • Ensure 9-5/8"BTC x CDS 40 XO on rig floor and M/U to FOSV. • R/U fill-up line to fill casing while running. • Ensure all casing has been drifted on the location prior to running. • • Be sure to count the total#of joints on the location before running. • Keep hole covered while R/U casing tools. • Record OD's, ID's, lengths, S/N's of all components w/vendor&model info. 12.3 P/U shoe joint,visually verify no debris inside joint. 12.4 Continue M/U&thread locking shoe track assy consisting of: • (1) Shoe joint w/float shoe bucked on (thread locked). • (1)Joint with coupling thread locked. • (1)Joint with float collar bucked on pin end&thread locked. • Install (2)centralizers on shoe joint over a stop collar. 10' from each end. • Install (1)centralizer,mid tube on thread locked joint and on FC joint. • Ensure proper operation of float equipment. 12.5 Continue running 9-5/8" surface casing • Fill casing while running using fill up line on rig floor. • • Use"API Modified"thread compound. Dope pin end only w/paint brush. • M/U connections to the base of the triangle stamped on the pin end. Note M/U torque values required to achieve this position. Estimated torque to reach base of triangle: 10,750 ft-lbs. • After making up several connections, use the torque required to M/U to base of triangle as the M/U torque and continue running string. • Install (1)centralizer every other joint to 300'. Do not run any centralizers above 300' in the event a top out job is needed. • Utilize a collar clamp until weight is sufficient to keep slips set properly. 9-5/8" BTC Estimated M/U Torque Casing OD Est Torque to Reach Triangle Base 9-5/8" 9,630 ft-lbs Page 20 Version 0 July, 2014 Beaver Creek#24 Drilling Procedure Rev 0 Hilcorp Energy Cornpsny Tenaris Casing and Tubing Performance Data Choose pipe size,wall thickness and steel grade to view API connection options and performance data. Size v Wall ' Grade • Connection f Unit Pipe Body Data GEOMETRY Nominal OD 9.625 in Wall Thickness 0.395 in API Drift Diameter 8.679 in Nominal Weight 40.00 Ibsift Nominal ID 8.835 in Alternate Drift Diameter 8.75 in Plain End Weight 38.97 Bas/ft Nominal Cross Section 11.454 sq in PERFORMANCE Steel Grade L80 Minimum Yield 80,000 psi Minimum Ultimate 95,000 psi Body Yield Strength 916,000 lbs Internal Yield Pressure 5,750 psi Collapse Pressure 3,080 psi 4I f�► Connection Data GEOMETRY Regular OD 10.625 in Threads Per Inch 5 Make-Up Thread Turns 1 PERFORMANCE Steel Grade L80 Minimum Yield 80,000 psi Minimum Ultimate 95,000 psi Joint Strength 947,000 lbs Internal Pressure 5,750 psi Resistance TenarisHvdril Premium Connections Print Contact Us Ver 8.6 12.6 Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 12.7 Slow in and out of slips. 12.8 P/U casing hanger joint and M/U to string. Casing hanger joint will come out to the rig with the landing joint already M/U. Position the shoe as close to TD as possible. Strap the landing joint while it is on the deck and mark the joint at(1) ft intervals to use as a reference when landing the hanger. 12.9 Lower string and land out in wellhead. Confirm measurements indicate the hanger has correctly landed out in the wellhead profile. Page 21 Version 0 July, 2014 Beaver Creek#24 II Drilling Procedure Rev 0 Hilcorp Energy Company 12.10 R/U circulating equipment and circulate the greater of 1 x casing capacity or 1 x OH volume. Elevate the hanger offseat to avoid plugging the flutes. Stage up pump slowly and monitor losses closely while circulating. 12.11 After circulating, lower string and land hanger in wellhead again. Page 22 Version 0 July,2014 Beaver Creek#24 Drilling Procedure Rev 0 Hilcorp Energy Company 13.0 Cement 9-5/8" Surface Casing 13.1 Hold a pre job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud&water can be delivered to the cmt unit at acceptable rates. • How to handle cmt returns at surface. • Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. • Positions and expectations of personnel involved with the cmt operation. 13.2 Document efficiency of all possible displacement pumps prior to cement job 13.3 R/U cmt head(if not already done so). Ensure top and bottom plugs have been loaded correctly. 13.4 Pump 5 bbls 10 ppg spacer. Test surface cmt lines. 13.5 Pump remaining 30 bbls of 10 ppg spacer. 13.6 Drop bottom plug. Mix and pump cmt per below recipe. 13.7 Cement volume based on annular volume+ 50%open hole excess. Job will consist of lead& tail, TOC brought to surface. Estimated Total Cement Volume: Section: Calculation: Vol (BBLS) Vol (ft3) 12.0 ppg LEAD: 80' x .129 bpf= 10.3 57.8 16" Conductor x 9-5/8" casing annulus: 12.0 ppg LEAD: (3000' —80')x .0558 bpf x 1.5 = 244.4 1372 12-1/4" OH x 9-5/8" Casing annulus: Total LEAD: 254.7 bbl 1429.8 ft3 TAIL: (3500'-3000') x .0558 bpf x 1.5 = 41.9 235.3 12-1/4" OH x 9-5/8" Casing annulus: TAIL: 90 x .096 bpf = 8.7 48.8 9-5/8" Shoe track: Total TAIL: 50.6 bbl 284.1 ft3 Page 23 Version 0 Jul}. 2014 Beaver Creek#24 Drilling Procedure Rev 0 Hilcorp P,nergy Company Cement Slurry Design: Lead Slurry (3000' MD to surface) Tail Slurry(3500' to 3000' MD) System Extended Conventional Density 12 lb/gal 15.4 lb/gal Yield 2.46 ft3/sk — 1.22 ft3/sk y-- Mixed 'Mixed Water 14.349 gal/sk 5.507 gal/sk Mixed Fluid 14.469 gal/sk 5.507 gal/sk Code Description Concentration Code Description Concentration G Cement 94#/sk A Cement 94#/sk D110 Retarder 0.15 gal/sk BWOC D046 Anti Foam 0.2% BWOC Additives D046 Anti Foam 0.2% BWOC D065 Dispersant 0.4% BWOC D079 Extender 2.0% BWOC S002 CaCl2 0.35% BWOC D020 Extender 3.0% BWOC D177 CaCl2 0.1% BWOC 13.8 Attempt to reciprocate casing during cement pumping if hole conditions allow. Keep the hanger elevated above the wellhead while working. If the hole gets "sticky", land the hanger on seat and continue with the cement job. 13.9 After pumping cement, drop top plug and displace cement with 9.0 ppg 6%KCL PHPA. 13.10 Ensure cement unit is used to displace cmt so that volume tracking is more accurate. 13.11 Displacement calculation: 3500'- 80' =3420' x .0758 bpf=259.2 bbls 13.12 Monitor returns closely while displacing cement. Adjust pump rate if necessary. If hanger flutes become plugged, open wellhead side outlet in cellar and take returns to cellar. Be prepared to pump out fluid from cellar. Have some sx of sugar available to retard setting of cement. Page 24 Version 0 July,2014 Beaver Creek#24 II Drilling Procedure Rev 0 Hilcorp Emu Cmpany 13.13 Do not overdisplace by more than V2 shoe track volume. Total volume in shoe track is 8.7 bbls. • Be prepared for cement returns to surface. If cmt returns are not observed to surface, be prepared to run a temp log between 12— 18 hours after CIP. • Be prepared with small OD top out tubing in the event a top out job is required. The AOGCC will require us to run steel pipe through the hanger flutes. The ID of the flutes is 1.5". 13.14 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats are holding. If floats do not hold, pressure up string to final circulating pressure and hold until cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating pressure if pressure must be held. 13.15 R/D cement equipment. Flush out wellhead with FW. 13.16 Back out and L/D landing joint. Flush out wellhead with FW. 13.17 M/U pack-off running tool and pack-off to bottom of Landing joint. Set casing hanger packoff. Run in lock downs and inject plastic packing element. 13.18 Lay down landing joint and pack-off running tool. Ensure to report the following on wellez: • Pre flush type,volume(bbls)&weight(ppg) • Cement slurry type, lead or tail,volume&weight • Pump rate while mixing,bpm,note any shutdown during mixing operations with a duration a. Pump rate while displacing,note whether displacement by pump truck or mud pumps,weight&type of displacing fluid b. Note if casing is reciprocated or rotated during the job c. Calculated volume of displacement,actual displacement volume,whether plug bumped& bump pressure, do floats hold d. Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating pressure e. Note if pre flush or cement returns at surface&volume f. Note time cement in place g. Note calculated top of cement h. Add any comments which would describe the success or problems during the cement job Send final "As-Run" casing tally & casing and cement report to mmyers(dhilcorp.corn. This will be included with the EOW documentation that goes to the AOGCC. Page 25 Version 0 July,2014 Beaver Creek#24 Drilling Procedure Rev 0 Hilcorp I±nergy Company 14.0 BOP N/U and Test 14.1 N/D the diverter. 14.2 N/U Seaboard multi-bowl wellhead assy. Install 9-5/8"packoff P-seals. Test to 3000 psi. 14.3 N/U 11"x 5M T3-Energy BOP as follows: • BOP configuration from Top down: 11"x 5M T3-Energy annular BOP/11"x 5M T3-Energy Model 6011i double ram/11"x 5M mud cross/11"x 5M T3-Energy Model 6011i single ram • Double ram should be dressed with 2-7/8 x 5" VBRs in top cavity, blind ram in btm cavity. • Single ram should be dressed with 2-7/8 x 5"VBRs • N/U bell nipple, install flowline. • Install (2)manual valves&a check valve on kill side of mud cross. • Install (1)manual valve on choke side of mud cross. Install an HCR outside of the manual valve. 14.4 Run 4-1/2"BOP test assy, land out test plug(if not installed previously). • Test BOP to 250/4000 psi for 10/10 min. Test annular to 250/2500 psi for 10/10 min: • Ensure to leave"B" section side outlet valves open during BOP testing so pressure does not build up beneath the test plug. 14.5 R/D BOP test assy. 14.6 Dump and clean mud pits, send spud mud to G&I pad for injection. 14.7 Mix 9.0 ppg 6%KCL PHPA mud system. 14.8 R/U mud loggers for production hole section. 14.9 Set 10"ID wearbushing in wellhead. 14.10 Rack back as much 4-1/2"DP in derrick as possible to be used while drilling the hole section. Page 26 Version 0 July,2014 Beaver Creek#24 II Drilling Procedure Rev 0 Hilcorp Energy C,empNy 15.0 Drill 8-1/2" Hole Section 15.1 P/U 8-1/2" directional BHA. ' 15.2 Ensure BHA components have been inspected previously. 15.3 Drift and caliper all components before M/U. Visually verify no debris inside components that cannot be drifted. 15.4 TF offset is measured accurately and entered correctly into the MWD software. 15.5 Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics calculations and recommended TFA is attached below. 15.6 Workstring will be 4.5" 16.6# S-135 CDS40. Page 27 Version 0 July,2014 Beaver Creek#24 II Drilling Procedure Rev 0 Hilcorp Energy Company 15.7 8-1/2" BHA: COMPONENT DATA G Item ..,...� Top Length. Cumult' �. Description erial Number': M } (in) (in - Connec (ff} Length (f13,, 1 HDBS-FX65D PDC 8.400 2.500 8.500 172.13 P 4-117 REG 1.00 1.00 2 7"SperryDrii Lobe 7i8-6.0 stg 7.000 4.952 93.13 B 4-1:2'1F 27.38 28.38 Stabilizer 7.750 3 Non Mag Float Sub 6.750 2.750 131.71 B 4-112"IF 3.00 31.38 4 Integral Blade Stabilizer(NM) 6.750 2.813 8.375 100.77 B 4-1/2"IF 5.00 36.38 . 5 6 3.4"DM(Directional) 6.750 3.125 133 40 B 4-112'IF 9.20 45.58 6 6 34"BAT (Sonic) 6.750 1.905 97.70 B 4-1(2"IF 20.30 65.89 , 7 6 3.4'DGR!Gamma) 6.750 1.920 97.SC B 4-N2"IF 4.55 70.44 8 6 34'EWR-P4 (Resistively) 6.750 2.000 134 30 B 4-112"IF 12.10 82.54 9 6 3/4"HCIM (Processor) - 6.750 1920 131 70 B 4-t12"IF 4.97 87.51 10 6 3/4"ALD (Density) 6.750 1.920 8.250 134.30 B 4-112"IF 14 54 102.05 Stabilizer 8.250 11 6 314'CTN(Neutron) 6.750 1.905 1 32.30 B 4-12"IF 1 1.84 113.89 12 6 3.%4"TM-HOC(Pulser) 6.900 3.250 103-60 B 4-112-IF 15.59 129.48 13 Non Mag Flex Drill Col a'• 6.750 2.813 13077 B 4-112"IF 30 00 159.48 14 Non Mag Flex Drill Cola- 6.750 2.813 100 77 B 4-112"IF 30.00 189.48 15 8 Joints 5"HWDP 5.000 3.000 49.3C 240.00 429.48 16 Weatherford 6-114"Jars 6.250 2.250 91.01 6 4-1.2"IF 30.00 459.48 17 19 Joints 5"HWDP 5.000 3.000 49.30 570.00 1029.48 ,„1't t '� 1029.48 Bit Number Nozzles : 5x13 Bit Size (in) : 8.5C0 TFA (int) :0.6481 Manufacturer Dull Grade In . Model Dull Grade Out . Serial Number .• MOTOR DATA Motor Number : 1 Bend (deg) . OD (in) : 7.000 Nozzles (32nd) . Manufacturer : Sperry Drilling Avg Diff Press . Model SperryDrill Cumul Cir Hrs . Serial Number . Page 28 Version 0 July,2014 Beaver Creek#24 Drilling Procedure Rev 0 Hilcorp Energy Company 15.8 Primary Bit: HALLIBURTON 8-112" (216mm) FX55 PRODUCT SPECIFICATIaNS Cutter Type Y3.-Extreme Drilling ,. D:W>C Cade M424 + ' Hedy T3pc M-.7 R1X Total Cutter Count diJ e Carnet et Distribte on1:0Nit •k »" Face 0 26 Gauge 5 5 Up[kill 5 9 Number of Duce Norjlcs 5 Number of M,ilium Nonlcs 0 Number of Smell Nortdes 0 Number of Micro Nortks 0 Number of Ports 0 �: Funk Slot Area lsginl 12.76 .�ti ` " Normalised Face Volume 57.06% API Connection 4-1,2 REG.PRI J Reccnmcndcd Make-Up Torque° 12.461—17.766 F1 1bs_ Nominal Dimensions" Make-Up Face to Nose 11.11 in-282 to Gauge Length tet-51 to eint Sion cLength 0in_0to Spunk Diameter bin-152 min Break Out Plate lMat.N.1-egacyts1 181954'441110 Approximate shipping Weight 150Lbs._68Kg. 'SPECIAL FEATURES V'p-[kill Cutters on Gage Pads.Ir32"Relieved Ciage Material#687916 •Bit rpo:ifre.recommendsd make-up torque is a function of the bit D.D.and actual bit suds 0.D.unliral as specifini ns API RP7Ci Section A 14.1. •`Dcsiiu dimensions arc nominal and may Nary sligiul;m ntanufantued product.llallibinten Drill Bits and Services models are ecotisawusly reviewed and refined Product sperrfcatlons may chance without nonce. r)2012 Ilallibutton.All rights r>.sser cd.Saks of Nallihurton products and services will be in accord solely with the terms and conditions contained in the contract between Ilalliburton and the customer that is applicable to the sale. www.halliburton.corn Page 29 Version 0 July, 2014 Beaver Creek#24 Drilling Procedure Rev 0 Hilcorp Ana Caupsr 15.9 8-1/2"hole section mud program summary: Weighting material to be used for the hole section will be salt and calcium carbonate. Additional calcium carbonate will be on location to weight up the active system (1)ppg above highest anticipated MW. 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: 9.0 ppg 6%KCL PHPA fresh water based drilling fluid. Properties: MD Mudi ght Viscosity Plastic Viscosity Yield Point pH HPHT 3500'- 10.808' 9.0— 10.0 . 40-53 15-25 15-25 8.5-9.5 < 11.0 System Formulation: 6% KCL EZ Mud DP Product Concentration Water 0.905 bbl KCl 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 15-20 ppb(5 ppb of each) BAROID 41 as required for a 9.0—10.5 ppg ALDACIDE G 0.1 ppb BARACOR 700 1 ppb BARASCAV D 0.5 ppb (maintain per dilution rate) I 15.10 TIH w/8-1/2"directional assy to TOC. Shallow test MWD and LWD on trip in. Note depth TOC tagged on AM report. 15.11 R/U and test casing to 3000 psi/30 min. Ensure to record volume/pressure and plot on FIT graph. AOGCC reg is 50%of burst. 15.12 Drill out shoe track and 20' of new formation. 15.13 CBU and condition mud for FIT. V \i.0 Page 30 Version 0 July,2014 Beaver Creek#24 Drilling Procedure Rev 0 Hilcorp Enemy Company 15.14 Conduct FIT to 11 ppg EMW. ✓ Note: Offset field test data predicts frac gradient at the 9-5/8"shoe to be btwn 15- 16 ppg EMW. An 11 ppg FIT results in a 2 ppg kick margin while drilling with the planned MW of 9 ppg• • 15.15 Drill 8-1/2"hole section to 10,808' MD/ • Pump sweeps and maintain mud rheology to ensure effective hole cleaning. • • Pump at 400 - 500 gpm. Ensure shaker screens are set up to handle this flowrate. • Utilize inlet experience to drill through coal seams efficiently. Coal seam log will be provided by Hilcorp Geo team, try to avoid sliding through coal seams. Work through coal seams once drilled. • Keep swab and surge pressures low when tripping. • Make wiper trips every 500' or every couple days unless hole conditions dictate otherwise. • Ensure shale shakers are functioning properly. Check for holes in screens on connections. • Adjust MW as necessary to maintain hole stability. Keep HTHP fluid loss< 10. • Take MWD surveys every other stand drld. Surveys can be taken more frequently if deemed necessary. • Take (3) sets of formation samples every 20'. Mud loggers should compile Pixler plots and • QFT 2 analysis for Lower Tyonek to total depth. 15.16 At TD;pump sweeps, CBU, and pull a wiper trip back to the 9-5/8" shoe. 15.17 TOH with the drilling assy, laying down drill pipe and BHA. 15.18 Install 5-1/2"pipe rams in BOP stack and RU and test. Page 31 Version 0 July,2014 Beaver Creek#24 Drilling Procedure Rev 0 Hilcorp 13ncrgy Company 16.0 Run 5-1/2" Production Casing 16.1. R/U Weatherford 5-1/2" casing running equipment. • Ensure 5-1/2"DWC/C HT x 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 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. 16.2. P/U shoe joint,visually verify no debris inside joint. 16.3. Continue M/U&thread locking shoe track assy consisting of: • (1) Shoe joint w/shoe bucked on &threadlocked(coupling also thread locked). • (1)Joint with float collar bucked on pin end&threadlocked (coupling also thread locked). • Solid body centralizers will be pre-installed on shoe joint an FC joint. • Leave centralizers free floating so that they can slide up and down the joint. • Ensure proper operation of float shoe and float collar. • Utilize a collar clamp until weight is sufficient to keep slips set properly 16.4. Continue running 5-1/2"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 joint across zones of interest,TBD after LWD. • Install solid body centralizers on every other joint to 9-5/8"shoe. Leave the centralizers free floating. • Pick up swell packer and place in string at approximately 3000'. 16.5. Continue running 5-1/2"production casing 5-1/2" DWC/C HT M/U torques Casing OD Minimum Maximum Yield Torque 5.5" 12,000 ft-lbs 13,800 ft-lbs 18,700 ft-lbs Page 32 Version 0 July,2014 Beaver Creek#24 Drilling Procedure Rev 0 Hilcorp Energy Company Technical Specifications Connection Type: Size(O.D.): Weight(Wall): Grade: DWC.0-HT Casing 5-1/2 in 17.00 Rift(0.304 in) P-110 standard radeMaterial P-110 Grade VIM 110,000 Minimum Yield Strength(psi) 1111111111111111111.111111111,U BA 125,000 Minimum Ultimate Strength(psi) VAM USA 4424 W.Sam Houston Pkwy.Siite 150 Pipe Dimensions Houston.Tx 77041 Phone:713-479-3200 5.500 Nominal Pipe Body 0.D. (in) Fax:713-479-3234 4.892 Nominal Pipe Body I.D.(in) E-mail:VAMUSAsales 'vam-usa.com 0.304 Nominal Wall Thickness(in) 17.00 Nominal Weight (Ibstft) 16.89 Plain End Weight(lbs/ft) 4.962 Nominal Pipe Body Area(sq in) Pipe Body Performance Properties 546,000 Minimum Pipe Body Yield Strength(lbs) 7,480 Minimum Collapse Pressure(psi) : 10,640 Minimum Internal Yield Pressure(psi) 9,700 Hydrostatic Test Pressure(psi) Connection Dimensions 6.050 Connection 0.D. (in) 4.892 Connection I.D. (in) 4.767 Connection Drift Diameter(in) ') 4.13 Make-up Loss(in) 4.962 Critical Area(sq in) 100.0 Joint Efficiency(%) Connection Performance Properties 546,000 Joint Strength (lbs) .' 22,940 Reference String Length(ft) 1.4 Design Factor 568,000 API Joint Strength (lbs) (' 546,000 Compression Rating (lbs) 7,480 API Collapse Pressure Rating (psi) 10,640 API Internal Pressure Resistance(psi) 91.7 Maximum Uniaxial Bend Rating[degrees/100 ft] ( Appoximated Field End Torque Values 12,000 Minimum Final Torque (ft-lbs) 13,800 Maximum Final Torque(ft-lbs) 18,700 Connection Yield Torque(ft-ibs) For detailed information on performance properties,refer to DWC Connection Data Notes on following page(s). Page 33 Version 0 July, 2014 Beaver Creek#24 Drilling Procedure Rev 0 Hilcorp Energy Arany 16.6. Run in hole w/5-1/2" casing to the 9-5/8" casing shoe. 16.7. Fill the casing with fill up line and break circulation every 1,500 feet to the window or as the hole dictates. 16.8. Obtain slack off weight, PU weight, rotating weight and torque of the casing. 16.9. Circulate 2X bottoms up at shoe, ease casing thru shoe. 16.10. Continue to RIH w/casing no faster than 1 jt./minute. Watch displacement carefully and avoid surging the hole. Slow down running speed if necessary. 16.11. Set casing slowly in and out of slips. 16.12. PU 5-1/2"X 8-1/2" swell packer to be placed at approximately 3000'. Swell packer should have 10' handling pups installed on both ends with bow spring centralizers on pups. 16.13. Swedge up and wash last 2 joints to bottom. P/U 5' off bottom. Note slack-off and pick-up weights. 16.14. Stage pump rates up slowly to circulating rate. Circ and condition mud with casing on bottom. Circulate 2X bottoms up or until pressures stabilize and mud properties are correct and the shakers are clean. Reduce the low end rheology of the drilling fluid by adding water and thinners. 16.15. Reciprocate string if hole conditions allow. Circ until hole and mud is in good condition for cementing. Page 34 Version 0 July,2014 Beaver Creek#24 Drilling Procedure Rev 0 Hilcorp Energy Company 17.0 Cement 5-1/2" Production Casing 17.1. Hold a pre job safety meeting over the upcoming cmt operations. Make room in pits for volume gained during cement job. Ensure adequate cement displacement volume available as well. Ensure mud&water can be delivered to the cmt unit at acceptable rates. • How to handle cmt returns at surface, regardless of how unlikely it is that this should occur. • Which pump will be utilized for displacement, and how fluid will be fed to displacement pump. • Positions and expectations of personnel involved with the cmt operation. • Document efficiency of all possible displacement pumps prior to cement job. 17.2. Attempt to reciprocate the casing during cmt operations until hole gets sticky 17.3. Pump 5 bbls of 12.5 ppg Mud Push spacer. 17.4. Test surface cmt lines to 4500 psi. 17.5. Pump remaining 30 bbls 10.5 ppg Mud Push spacer. 17.6. Mix and pump lead and tail cement per below recipe. Ensure cement is pumped at designed weight. Job is designed to pump 35%OH excess. Section: Calculation: (BBLS) Vol (ft3) 9-5/8" x 5-1/2" Csg Overlap: 500' x 0.0464 = 23.2 130.4 8-1/2"OH x 5-1/2" Casing: (10808—3500)x 0.0408 x 1.35 = 402.5 2260.0 Shoe Track: 80' x 0.02325 = 1.9 10.4 Total Volume : 427.6 2400.8 - -7 ; Page 35 Version 0 July,2014 Beaver Creek#24 Drilling Procedure Rev 0 Hilcorp Energy Company EASYBLOK (10808' to 3000') System Conventional Density 15.3 lb/gal Yield 1.36 ft3/sk Mixed Water 5.93 gal/sk Mixed Fluid 5.93 gal/sk Code Description Concentration Class G Cement 94#/sk D046 Foam Preventer 0.2% BWOC D202 Dispersant 1.5% BWOC Additives D400 EASYBLOK 0.8%BWOC D154 Extender 8.0% BWOC D174 Expanding Additive 1.5% BWOC D198 Retarder 0.3% BWOC 17.7. Drop wiper plug and displace with produced water. 17.8. If hole conditions allow—continue reciprocating casing throughout displacement. This will ensure a high quality cement job with 100%coverage around the pipe. 17.9. If elevated displacement pressures are encountered, position casing at setting depth and cease reciprocation. Monitor returns &pressure closely while circulating. Notify Drilling Foreman immediately of any changes. 17.10. Bump the plug and pressure up to 500 psi over final lift pressure. Hold pressure for 3 minutes. 17.11. Do not overdisplace by more than '/z shoe track. Shoe track volume is 1.9 bbls. Page 36 Version 0 July,2014 Beaver Creek#24 Drilling Procedure Rev 0 Hilcorp Energy Campo 17.12. Bleed pressure to zero to check float equipment. Watch for flow.Note amount of fluid returned after bumping plug and releasing pressure. 17.13. RD cementers and flush equipment. 17.14. WOC minimum of 12 hours,test casing to 3000 psi and chart for 30 minutes. Ensure to report the following on wellez: • Pre flush type,volume(bbls)&weight(ppg) • Cement slurry type,lead or tail,volume&weight • Pump rate while mixing,bpm,note any shutdown during mixing operations with a duration i. Pump rate while displacing,note whether displacement by pump truck or mud pumps,weight&type of displacing fluid j. Note if casing is reciprocated or rotated during the job k. Calculated volume of displacement,actual displacement volume,whether plug bumped&bump pressure,do floats hold I. Percent mud returns during job,if intermittent note timing during pumping of job.Final circulating pressure m. Note if pre flush or cement returns at surface&volume n. Note time cement in place o. Note calculated top of cement p. Add any comments which would describe the success or problems during the cement job Send final "As-Run"casing tally&casing and cement report to mmyers@hilcorp.com. This will be included with the EOW documentation that goes to the AOGCC. Page 37 Version 0 July,2014 Beaver Creek#24 Drilling Procedure Rev 0 Hilcorp Energy CAwnpany 18.0 RDMO 18.1. Install BPV in wellhead 18.2. N/D BOPE 18.3. N/U temp abandonment cap 18.4. RDMO Saxon Rig#169 Page 38 Version 0 July,2014 Beaver Creek#24 Drilling Procedure Rev 0 Hilcorp I nergy('ompany 19.0 BOP Schematic • .5 ' J ii yin iii I-1 ail rfii frt\rtti L VIodet 60111 :I Ill iii III III Ill zi i.:iaI (6�r1 T 3=Here *Mite o t4ilrtilodei 71 2 -�r!!�" 11 SJIJ 6 L AJD Iii ISI III Iii 111 2.1L�' c lI !1IIi �� iii iii al Iii Ito — 2 1115 511 I.li Sri, - 3 1/8 5M Choke Side 1.11' =CFrzir .5., \1J3,11u62'EL .,,. 2 E .wevr____O 11' ,A.:ri mi,__ ,. - Grade ill ill III fit •I :1 M.-- :07")t Ail a ,,, ti* III r P. Ni<Nil -zo': 51 Page 39 Version 0 July, 2014 11 Beaver Creek#24 Drilling Procedure Rev 0 Hilcorp Energy Company 20.0 Wellhead Schematic Beaver Creek New Drill-Saxon 169 16X95/8X51/2 Tree cap,Otis,5 1/8 SM FE X 9;S Otis Quick Union Bill .. aun Valve,Swab,WKM-M, -, i] 51/8 SM FE,HWO, i5, Nik n: DD trim *), L h 6111111111111 N. Valve,Wing,WKM-M, I: - : ' Valve,Wing,WKMM, it DD trim Valve,Upper Master, ,CA WKM-M,51/85M FE,HWO, '�� 4' DD trim u Crossover spool, '"� �� t1� 51/85M FE X51/810M FE �i�J Valve,Master,CIW-FC, :l) *. C 51/810M FE,HWO, °�C..,,�` EE trim `�� .6 b *J iij th Tubing head,Seaboard-S8, / 163/43M X11SM, ar , w/2-2 1/16 SM 550, •i �}�� - -1 95/8Pseal bottom a '�• k ti Starting head,Seaboard, * 1i- 16%3MX16"SOW BTM, WI D;II! ! -• Z,• il : 4. w/2-2 1/16 5M SSO '!! 1",i 0. -k 16" 9 5/8" 5 N" Page 40 Version 0 July, 2014 Beaver Creek#24 Drilling Procedure Rev 0 Hilcorp Energy Company 21.0 Days Vs Depth Days Vs Depth 0 —\\ —Beaver Creek 24 2000 — 4000 -- — - 13 6000 N co BO00 10000 --- 12000 0 5 10 15 20 25 30 Days Page 41 Version 0 July, 2014 Beaver Creek#24 II Drilling Procedure Rev 0 Hilcorp Energy Company 22.0 Geo-Prog GEOLOGICAL PROGNOSIS WELL NAME: BCU 24 (GR well from Pad 3) FIELD: Beaver Creek SURFACE: X=317473.83 LONG: -151.0173849 STATE: Alaska _ Y=2433936.29 LAT:60.6581479 BOTTOMHOLE X=319530.2 LONG. -151.0060319 TVD REF DATUM KB Y=2432240.3 LAT: 60.6533102 TVD REF ELEV - 179 18.6'KB(Saxon 169) COORD REF. SYSTEM NAD27 GROUND ELEV 160.6 PROPOSED TD: 10,900'MD/10,126 'TVD Objective: Beluga B18-B32 gas sands Geo Summary/ Justification: The goal of the BCU 24 is to test the Middle and Lower Beluga gas sands(B18-B32)on the eastern flank of the field between the BCU 13 and 16 RD wells ANTICIPATED FORMATION TOPS&GEOHAZARDS EXPECTED Critical Intersection Points TOP TOP NAME FORMATION FLUID TVD(FT) TVDSS(FT) Est.Pressure X Y +/- r' SHALLOW GAS Sterling water/gas 3,016 -2,837 1200-1300 psi 317633.6 2433757.2 30 B2 Sterling water/gas 5,058 -4,879 1900-2300 psi 318718.8 2432785.4 30 B4 Sterling water/gas 5,249 -5,070 1900-2300 psi 318826.0 2432689.5 30 UBC3 Beluga water/gas 6,068 -5,889 1000-3300 psi 319246.4 2432313.0 30 B18 Beluga gas 7,264 -7,085 1000-3400 psi 319480.1 2432103.7 30 B24 Beluga gas 7,777 -7,598 3000-3500 psi 319484.3 2432099.9 30 B28B Beluga gas 7,920 -7,741 3000-3600 psi 319484.3 2432099.9 30 B30 Beluga gas 8,198 -8,019 3000-3600 psi 319484.3 2432099.9 30 Tyonek Tyonek water 8,700 -8,521 3000-3600 psi 319484.3 2432099.9 30 TD 10,126 -9,947 See BHL above =Primary Objective =Secondary Objective TARGET RADIUS 50 ft E DATA COLLECTION REQUIREMENTS: Mud Logging: Full crew of4 for production hole section. 2 sets of washed&dried samples collected every 20 ftfrom KOP to TD. Pixer plots and sh LWD Data: Sperry Triple Combo E-Line Log Data: Page 42 Version 0 July, 2014 Beaver Creek#24 11 Drilling Procedure Rev 0 Hilcorp Energy Cornpsny 23.0 Anticipated Drilling Hazards 12-1/4" Hole Section: Lost Circulation: Ensure 500 lbs of medium/coarse fibrous 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/gel and gel extender. Sweep hole with gel or flowzan sweeps as necessary. Optimize solids control equipment to maintain density, sand content, and reduce the waste stream. Maintain YP btwn 25—45 to optimize hole cleaning and control ECD. Wellbore stability: Lithology through this zone is a composite of pebble conglomerate and sand in the upper intervals with intermittent clay matrix. Carbonaceous material and coal may be noted. Gravel sizes that are larger than normal can cause hole-cleaning problems. If encountered, be prepared to increase the viscosity. Excessive quantities of gravel and sand may indicate wellbore instability. Increase properties up to a YP of—50 -—60 lbs/100ft2 to combat this issue. Maintain low flow rates for the intial 200' of drilling to reduce the likelihood of washing out the conductor shoe. To help insure good cement to surface after running the casing, condition the mud to a YP of 25 —30 prior to cement operations. Do not lower the YP beyond 25 to avoid trouble with sands that may be found on this well. Have Desco DF, SAPP, and water on hand to ensure the desired rheologies can be achieved. H2S: 7 H2S is not present in this hole section. No abnormal pressures or temperatures are present in this hole section. Page 43 Version 0 July,2014 Beaver Creek#24 Drilling Procedure Rev 0 Hilcorp Energy Company 8-1/2" Hole Section: Lost Circulation: • Ensure 1000 lbs of each of the different sizes of Calcium Carbonate are available on location to mix LCM pills at moderate product concentrations. Hole Cleaning: g Maintain rheology w/viscosifier as necessary. Sweep hole w/20 bbls hi-vis pills as necessary. Optimize solids control equipment to maintain density and minimize sand content. Maintain YP btwn 20 - 30 to optimize hole cleaning and control ECD. Wellbore stability: Maintain MW as necessary using additions of Calcium Carbonate as weighting material. A torque reduction lube may be used in this hole section in concentrations up to 3% if needed. Maintain 6%KCI in system for shale inhibition. Coal Drilling: The following lessons were learned from extensive experience drilling coal seams in Cook Inlet. The need for good planning and drilling practices is also emphasized as a key component for success. • Keep the drill pipe in tension to prevent a whipping effect which can disturb coal sections. • Use asphalt-type additives to further stabilize coal seams. • Increase fluid density as required to control running coals. • Emphasize good hole cleaning through hydraulics, ROP and system rheology. H2S: � H2S is not present in this hole section. i No abnormal temperatures are present in this hole section. Page 44 Version 0 July, 2014 Beaver Creek #24 II Drilling Procedure Rev 0 Hilcorp Anergy Company 24.0 Saxon Rig 169 Layout 221.12 .Ilii .- Ilei _ _- 1ill1 _t _.I1J.� '�. 1,°' sxuFnyyJ Ips— �IIIII �M�� NI—...*t..,15. I -.7 IIIA _'lll_I �'ark is — — - -- - _ c+..� rilllllll • .c'f IIII IIIIII �l [ _ _ I. l� ^ II I -u ._ 6_ ._ muul11 1111m rnrl x.xrav�. Mir' - 'IIIfIIIiII M IIr - _ I If 441 III mi, I■� ■ in ...0 IRS IM ,-,- Emaimi - II_f. I - Page 45 Version 0 July, 2014 Beaver Creek#24 Drilling Procedure Rev 0 Hilcorp I'.nergy Company 25.0 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 46 Version 0 July,2014 Beaver Creek#24 II Drilling Procedure Rev 0 Hilcorp Fncrgy('.ompany 26.0 Choke Manifold Schematic t r 4 I 8 $ 1 -, P-12 g — —�— •j, fie 1,4'. 111000 11 0.1 ; a JIIP MN. I o .. (� w w "f:' L litp/e r�M� . ! t L, 'w.� Marl "m. Chi f:� ! $ ; flt [r , �ir :44..,..,1 rt11� ik ,1.- iV , , e. dl,,.. enilt_ --r v • �� o 10,117 z y w .*A�`a r * ci 1 ( l e E • !t-7 1111111111111111 ." w�14 Ii ; ��1I t p 0 It l til 1 11_: rc2�+ o . p F t TT 11 it ,...__. __.__y _i, I/ I I A arE t Page 47 Version 0 July, 2014 Beaver Creek#24 Drilling Procedure Rev 0 Hilcorp Energy Company 27.0 Casing Design Information Calculation & Casing Design Factors Beaver Creek Unit DATE:6/20/2014 WELL: Beaver Creek#24 FIELD: Beaver Creek DESIGN BY:Monty M Myers Design Criteria: Hole Size 12-1/4" Mud Density: 8.8 ppg Hole Size 8-1/2" Mud Density: 9.0 ppg Hole Size Mud Density: Drilling Mode MASP: 1462 psi(see attached MASP determination&calculation) MASP: Production Mode MASP: 2592 psi(see attached MASP determination&calculation) Collapse Calculation: Section Calculation 1 Normal gradient external stress(0.435 psi/ft)and the casing evacuated for the internal stress Casing Section Calculation/Specification 1 2 3 4 Casing OD 9-5/8" 5-1/2" Top(MD) 0 0 Top(TVD) 0 0 , Bottom(MD) 3,500 10,808 Bottom (TVD) 3,402 10,126 Length 3,500 10,808 Weight(ppf) 40 17 Grade L-80 P-110 Connection BTC DWC/C HT Weight w/o Bouyancy Factor(lbs) 140,000 183,736 Tension at Top of Section(lbs) 140,000 183,736 Min strength Tension(1000 lbs) 916 546 .................. Worst Case Safety Factor(Tension) 6.54 2.97 Collapse Pressure at bottom (Psi) 1:480 4,405 Collapse Resistance w/o tension(Psi) 3,090 7,480 Worst Case Safety Factor(Collapse) 2.09 1.70 MASP(psi) 1,135 2,592 1 Minimum Yield(psi) 5,750 10,640 Worst case safety factor(Burst) 5.07 4.10 Page 48 Version 0 July, 2014 Beaver Creek#24 Drilling Procedure Rev 0 Hilcorp Energy Company 28.0 8-1/2" Hole Section MASP Maximum Anticipated Surface Pressure Calculation 8-1/2"Hole Section Hi1coX Beaver Creek#24 Beaver Creek Unit MD TVD Planned Top: 0 0 Planned TD: 10808 10126 Anticipated Formations and Pressures: Formation TVD Est Pressure Oil/Gas/Wet PPG Grad Shallow Gas 3016 1300 WATER/GAS 8.3 0.431 B2 5058 2300 WATER/GAS 8.7 0.455 B4 5249 2300 WATER/GAS 8.4 0.438 UBC3 6068 2850 WATER/GAS 9.0 0.470 B18 7264 3400 GAS 9.0 0.468 B24 7777 3500 GAS 8.7 0.450 B28B 7920 3600 GAS 8.7 0.455 B30 8198 3600 GAS 8.4 0.439 Tyonek 8700 3600 GAS 8.0 0.414 TD 10126 3600 WATER 6.8 0.356 Offset Well Mud Densities Well MW range Top(TVD) Bottom(ND) Date Beaver Creek 1B 9.2-9.9ppg _ 5,200 10,900 2014 BeaverCreekll 8.8-9.6ppg 400 8,684 2003 Beaver Creek 13 8.5-10.4 ppg 0 10,182 2003 Beaver Creek 14A 9.0-9.4ppg 5,000 9,450 2014 BeaverCreek7A 9.0-9.3 2,400 _ 8,929 2014 Beaver Creek 12A 9.0-9.4 4,500 9,578 2014 Assumptions: 1. Fracture gradient at shoe is estimated at 0.65 psi/ft based on field test data. 2. Maximum planned mud density for the 8-1/2"hole section is 9.5 ppg. 3. Calculations assume"Unknown"reservoir contains 100%gas(worst case). 4. Calculations assume worst case event is 100%evacuation of wellbore to gas. Fracture Pressure at 9-5/8"shoe considering a full column of gas from shoe to surface: 3401(ft)x 0.65(psi/ft)= 2211 psi 2211(psi)-[0.1(psi/ft)*3401(ft)]= 1871 psi MASP from pore pressure(unknown gas sand at TD,at 8.4 ppg,encountered while drilling) 10,126(ft)x 0.356(psi/ft)=3605 psi 3605(psi)-[(2/3)*0.1(psi/ft)*10126(ft)]+[(1/3)*0.435(psi/ft)*10126(ft)]= 1462 psi ) MASP from pore pressure during production mode(Complete evacuation to gas) fAk - F� q/ 10,126(ft)x 0356(psi/ft)=3605 p psi 3605(psi)-[0.1(psi/ft)*10,126(ft)]= 2592 psi Summary: A�h3r° 1. MASP while drilling 8-1/2"production hole is governed by pore pressure and evacuation of 2/3 wellbore to gas at 0.1 psi/ft. Page 49 Version 0 July, 2014 Beaver Creek#24 11 Drilling Procedure Rev 0 Hilcorp Energy Company 29.0 Spider Plot (NAD 27) (Governmental Sections) I Legend • BCU 24 SHL BCU 24 TPH BCU 24 BHL R. Other Surface Well Locations ECU 03RD BHL, Other Bottom Hole Locations P� - Well Paths Oil and Gas link Boundary 7 BCU 03 ENV uta rX ecu '' BCD 11 Bely f SOO7NO1OW A02 083 • SPL > - BCU 24 Slit_ BEAVER CREEK UNIT SCJ 04_.t-1 it BC Lt 06 43111• BCU 24 TPH 1, BCL is BHL107) e3ECU .3 EHL 7 �(} LIP09BHL ' �� � BBL' e�'1 BCL? 44 BHL 1 BCU 14 BHL I SCJ it EFh L4 / ff i tlClrl tczL#lEi�+ BCU DJ.%Beit' 9•:=J i_BHL" BCU 01EbH4;+ AIr8118 J,Ji Bf-L SOO6N010W €1 BCU 074$kite 4 1.=5v SC�i Beaver Creek Unit Feet BCU24 Alaska Stale Plane Zone 4..NA1327 A H1k wp MALL.11,1 hMaO Date:.7102014 Page 50 Version 0 July,2014 Beaver Creek#24 11 Drilling Procedure Rev 0 Hilcorp Energy Company 30.0 Surface Plat (As Staked) (NAD 27) 1-14-24;34208 12 SECTION UNE NOT TD SCALE —"*"1/4 ' E 37683546 __ I • • SECTION 34 T7N MOW SM.AK I . j4 � �- B,C.U,NO.24 � ( f AS-STAKED .z BEA'!ER CREEK U*i' " N:2433035.29 • P,AO 3 E:317473.111 ec ,,, **'`• LAT:60"39'29.694"N Io �1�1.��,.. / LONG:-151'011)2.615-W 1 / NAD27 ASP Zone 4 y / ''i''11 / ELEV:160.5' as�.o'.f... w., / NAVDBB 1P9 1656'FWL FWL - z� s�M / 1246'FNL \VIC ‘;.../4\ f , • ‘` �-4' NOTES I -"c1I BASIS OF GEODETIC CONTROL Alf NANO POSITION{EPOCH 203)IS AN OPUS SOLUTION FROM NGS COORDINATES STATIONS'KEN 1 CORS ARP'.`TL KA TALKEETNA CORS AAP',AND 7013 POTATO I POINT 3 ARP'TO ESTABLISH THE POSITION OF MCI 8601.THE GEODETIC POSITION OF SC1 WAS DETERMINED TO HAVE A LATITUDE OF 50-3850 021TrN AND A LONGITUDE OF 151•6212.30311'W.THE ALASKA STATE PLANE `%%%%%%11 COORDINATES{ASP;ZONE 4 ARE N=2429533.534 `�ty."t. Ate."' _ E.14531,83 065 P)., �I ELEV,131.31'(NAVDS5I *14 3#11—T ►*'r NORTH .„41....... 7)BASIS OF VERTICAL CONTROL IS NGS BM V881 I -. I _i _ PID TTO54II LOCATED WITHIN 1 HE MENAN SPUR I lE11 A.*UNE! HIGHWAY RIGHT OF WAY AT EWE FOSr 3.75 /! NIUHAVING AN ELEVATION OF 184 1513 FEET hwVO 104, J0�� i S5 COROING TO NGS PUBLISHED Cwt n. I 111151%%%% I `C:ALE :.�i' AC 3.0 COORDINATES COVERIED TO NAA 22 USING ,, CORPSCON CONVERSION SOI'TWARE BCU$24 W6..L AB-STAKE)SURFACE LOCATION (NAD27) BEAVEI CHEEK UNT PAD 3 ,/ _ lit ENGINEERING-TESTING I :.ATI i SECT ON,C). TO'C'ASt'I('7 NORTH SURVEYING-MAPPING I , ,r:(: 'I,WEST.SEWARD MERIDIAN ALASKA IIih ut Alastr l.l.c P.O.BOX 468 •X1.1 SOLOOTNA,AK 0E16&9 JOB NO. 143082 VOICE:(9071283-4218 FAX:007)283-3265 DRAWN BY Cosi*.het WWW.MCLANECO.00M BGB I DATE:6)26114 I Page 51 Version 0 July, 2014 Beaver Creek#24 111 Drilling Procedure Rev 0 Hilcorp Energy Company 31.0 Surface Plat (As Staked) (NAD 83) N 2a549CA 10 • • — - - SECTS7N LTTE NOT TO..... .E • --.• ' • �_ — r 1455B58®p 1 I SECTION 34 TTN R 10W SM.AK r•-- ..1 ` 1 2 BEAVER CREEK UNIT � PAD 3 _ B.C.U.NO 24 »>. AS-STAKED It 1� bG1. •.,. / N:2433897.18 / E.1457494.99 •y •`i'• LAT:50`3921.647'N / •.t.., • .�� � LONG;•151'01'10-631'4V 111,NW NAD83 ASP Zone 4 ,. ' ...„ bc�..o ;7 ELEV:160.5' (i NAVD8 • 11c11.."' 1656' 1Nt I I t `. P1246'FNL • \'' f 1 ......1.''',..--4 NOTES 1)BASIS Of GEODETIC CONTROL AND NAO83 POSITION(EPOCH 2O33)IS AN OPUS SOLUTION FROM NGS COORDINATES • STATIONS'BENI COPS ARP'.'TLKA I TALI'EETNA CORS ARP".AND TOT3 POTATO POINT 3 ARP TO ESTABLISH THE POSITION OF MCI BCR.THE GEODETIC POSITMON OF 503 • WAS DETERMINED TO HAVE A.LATITUDE OF •E ��*���11j BO.3e5O.O277TNAND ALONGITUDE OF ,1 OF /11 'N 151'°C)2'22.30311 W.THE:ALASKA STATE PLANE // = COORDINATES(ASP)ZONE I ARE :'�47M 1 N.24209335:11 • • *• NORTH 1~=5453963:065 <PQ % ELEV.131.91'1N4VGG811 jT'N'T 21BA51S OFVERT'IC.ALCONTROLISNGS8M'JBDA -L4I P[7T?tl!CELOCATED VI1IHIN1HfICENAISPUR• 1/ �Ir�OM '` G , 3u t HIGHWAY RIGHT OF WAY AT MILE POST 3.75 111X11%%%%% I S� I HAVING AN ELEVATION OF 164:55 FEET FOND SS ACCORDING TO NGS PUBLISHED DATA BCV*24 WELL AS—STAKED SURFACE LOCATION (NAD93) BEAVE#i CSC MIT PAD 3 ENGINEERING-TESTING SURVEYING-MAPPING I OCATION;SECTION 34, TOWNSHIP 7 NORTH RANGE 10 WEST,SEWARD MERIDIAN ALASKA 11iimri,m4rkw L Lt P.0 BOX 466 k1�CLA SOLDOTNA,AK 99669 JOB NO. 143082 VOICE:(907)28411 33-0218 FAX:(BD7)2833285 DRAWN BY Coniuttiv he WWA'.MCL.ANECG.00M BGB DATE:6126114 FIGURE 1 Page 52 Version 0 July,2014 Beaver Creek#24 Drilling Procedure Rev 0 Hilcorp Anergy Company 32.0 Directional Survey Page 53 Version 0 July, 2014 I $, Hilcorp Energy Company Beaver Creek Unit Beaver Creek Unit Beaver CK Unit 24 BCU 24 Plan: BCU-24 wp2.0 Standard Proposal Report 10 July, 2014 1 r og I II HALLIBURTON Sperry Drilling Services HALLIBURTON Projec.. Beaver Creek Unit Hilcorp Site: Beaver Creek Unit Sperry Drilling Well: Beaver CK Unit 24 Wellbore: BCU 24 BCU-24 wp2.0 CASING DETAILS -10007 TVD 1000- TVD TVDSS MD Name Size 3401.63 3222.53 3500.00 9-5/8 9 5/8" -500- 10125.90 9946.80 10808.02 5-1/2 51/2" 0- 500- - WELL DETAILS: Beaver CK Unit 24 1000- Ground Level: 160.50 +N/-S +E/-W Northing Fasting Latittude Longitude Slot 0.00 0.00 •2433936.29 • 317473.83 60.6582484 -151.0173929 1500- Start Build 2.50 REFERENCE INFORMATION 2000- Co-ordinate(N/E)Reference: Well Beaver CK Unit 24,True North ' Vertical(TVD)Reference: Plan:BCU 24 @ 179.10usft((160.5 GL+18.6 KB)) Measured Depth Reference: Plan:BCU 24 @ 179.10usft((160.5 GL+18.6 KB)) 2500- Calculation Method: Minimum Curvature Start 3604.12 hold at 3268.93 MD - 3000- --SHALLOW GAS - SURVEY PROGRAM Date:2014-06-17T00:00:00 Validated:Yes Version: 35007 9 5/8"/ Depth From Depth To Survey/Plan Tool - 18.60 3500.00 BCU-24 wp2.0(BCU 24) MWD+SC+sag 4000- 3500.00 10808.02 BCU-24 wp2.0(BCU 24) MWD+SC+sag c - 4500- FORMATION TOP DETAILS z TVDPath TVDssPath MDPath Formation r� 50007___82- 3016.10 2837.00 3052.73 SHALLOW GAS 84- 5058.10 4879.00 5447.42 B2 L _ 5249.10 5070.00 5671.97 B4 0 5500- 6068.10 5889.00 6634.82 UBC3 p 7264.10 7085.00 7943.44 B18 = Start Drop-2.00 7777.10 7598.00 8459.22 B24 to 6000- __ UBC3 --- 7920.10 7741.00 8602.22 B28B --- 8198.10 8019.00 8880.22 B30 8700.10 8521.00 9382.22 Tyonek a) 6500- 2 t- - 7000- Hilcorp Energy Company _ -- 818 Start 2348.80 hold at 8459.22 MD Calculation Method: Minimum Curvature 7500 -- Error System: ISCWSA BCU 24 Mid Tgt wp2 Scan Method: Closest Approach 3D ----R24 --- --- Error Surface: Elliptical Conic B28B Warning Method: Error Ratio 8000- 830- 8500- --Tyonek 90007 95007 10000- BCU 24 BHL Tgt wpb -TD at 10808.02 105007 5 1/2" BCU-24 wp2.0 11000- 11500 12000 -2000 -1500 -1000 -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 Vertical Section at 133.76°(1500 usft/in) .N EY Ej: odm O Q, - NO JJ _ _ —N i a'Y��i X00 NuaD= = - UUU 4 0)CR dCT)CO LO CO CO 2 e ami 0 0 j _oo m�� ++ �, z QQ mmm (� y�� ZW� c �� .,O (.4 -25 WW O O rnM /M� Y�I W C1�1�`1 F2 2 Or 1y• Q, Q) O V0 H J. N - E.) mNNV W - a a:• W O O p N } 010. b 00 - T' 0 0) m= () 200 0 0 O m E Z koro ov � a mA� N oo ¢ �«' ��' q N 3aa� < r'nio Ce :a Y 0 oma F Z 0 > > �J0 V F (pM0 NN 0, O N cn Er, mY3 w�ao a == m I W U N ONCC } O 03 m I I V 00 oW .LU-C15 ei —g 0100- Mc0 8 mm J0,, 1 I N �'NQ•O w O 00 Q VC03 I I t 0 O w c,c6 N cci' ?oma Zmrn N k w33 0 oWa II .4- - a O :?>pc a m r}p+i,� I I E M nog O N O d N N W E. I m 23== Mo .a 07 o, d O.p O 9e0- N f/1 m m C�Np x II N C 0 QU2 830 N C0) = 11 LU Et =cpQ53n l0 I-0o Z0 N II i _ - p V CUO.at Q00 N O U ��-. S ��UWw O00 O N M h 5� .. VEa v �0 I —25 La,O 2u7a \ N dodo E00 + oo \ - E O Q O C L m co 1 - Z WcnW NN M Z O c/} N _ 3 0 +O 0. 0 a o \ 3 .n o " I_-J Vo 0 C m '0 - 2�yy T, N N - 0) on O H mm N —0 ZS V 00 M M N N U - >OO�Nbb - N 800020000 LL0O6000 -- 3 I- ' t2 - 0,000000 0)00)0000 - 800N0<'10 - O eis, OMMO -00 -o COOG00)ONN 1 yMMhdCOCO _ ' ^L 10Ii1iM wgnnrnrnrn aMM )Mo)co N _ M v _ C)W 0COc000 0 - O W CNN V cOMM —h . J • Cc00,,°.°LOvv .� W zM V)V)N NN (-9 • MMMMMM z V V V V V V 8\ Z NNNNNN - 0 O• >> - p o + Garcpp cc;NN 0 \ _ + cv^pp h h ` NN )y _ -o T p. 00NN0 ✓ ZO000 CcpMcp ` 'Bo - + NMCOcO )% r_v cZi." C71- M m m ;‘,,t c, - aYN UUUV Q - • a> a) 'mm 8 m ca (6 Ncsi M mmm .,j - 00 00 00 i U - :.; ••cL> O m -Q 0 r.•y-. 25 _- 8 —8 O - g el 7 M "' 8 N —n U ata 7 i J U m - o —o 00 c - o S = — - - o 0 - v - —g n = _ -8- 3 M N U - m - 8 eibl —o MSM o =8 1.4 i M —o IS C V co - U CO —- 8 Z •J _ N 0 Ills U 3 al U Y A Gq - L L 8 o 8 8 S 0 0 8 8 0. - I (f) (m/gsn OOb)(+)uuoN/(-)gmos Halliburton HALLBU RTO Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 24 Company: Hilcorp Energy Company TVD Reference: Plan:BCU 24©179.10usft((160.5 GL+18.6 KB)) Project: Beaver Creek Unit MD Reference: Plan:BCU 24 @ 179.10usft((160.5 GL+18.6 KB)) . Site: Beaver Creek Unit North Reference: True . Well Beaver CK Unit 24 Survey Calculation Method: Minimum Curvature - Wellbore: BCU 24 Design: BCU-24 wp2.0 Project Beaver Creek Unit Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Site Beaver Creek Unit Site Position: Northing: 2,430,086.36 usft Latitude: 60.6475877 From: Map Easting: 314,428.19usft Longitude: -151.0340284 Position Uncertainty: 0.00 usft Slot Radius: 13-3/16" Grid Convergence: -0.90° Well Beaver CK Unit 24 Well Position +N/-S 0.00 usft Northing: 2,433,936.29 usft ' Latitude: 60.6582484 +E/-W 0.00 usft Easting: 317,473.83 usft • Longitude: -151.0173929 Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 160.50 usft Wellbore BCU 24 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2014 6/12/2014 17.02 73.63 55,453 Design BCU-24 wp2.0 Audit Notes: Version: Phase: PLAN Tie On Depth: 18.60 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 18.60 0.00 0.00 133.76 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +El-W Rate Rate Rate Tool Face (usft) (°) (°) (usft) usft (usft) (usft) (°/100usft) (°/100usft) (°1100usft) (°) 18.60 0.00 0.00 18.60 -160.50 0.00 0.00 0.00 0.00 0.00 0.00 2,000.00 0.00 0.00 2,000.00 1,820.90 0.00 0.00 0.00 0.00 0.00 0.00 3,268.93 31.72 128.63 3,205.09 3,025.99 -213.75 267.50 2.50 2.50 0.00 128.63 6,873.06 31.72 128.63 6,270.74 6,091.64 -1,396.77 1,748.01 0.00 0.00 0.00 0.00 8,459.22 0.00 0.00 7,777.10 7,598.00 -1,663.96 2,082.38 2.00 -2.00 0.00 180.00 10,808.02 0.00 0.00 10,125.90 9,946.80 -1,663.96 2,082.38 0.00 0.00 0.00 0.00 7/10/2014 5:34:28PM Page 2 COMPASS 5000.1 Build 70 Halliburton HALLIBURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 24 Company: Hilcorp Energy Company TVD Reference: Plan:BCU 24 @ 179.10usft((160.5 GL+18.6 KB)) Project: Beaver Creek Unit MD Reference: Plan:BCU 24 @ 179.10usft((160.5 GL+18.6 KB)) Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 24 Survey Calculation Method: Minimum Curvature Wellbore: BCU 24 Design: BCU-24 wp2.0 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) 460.50 18.60 0.00 0.00 18.60 -160.50 0.00 0.00 2,433,936.29 317,473.83 0.00 0.00 100.00 0.00 0.00 100.00 -79.10 0.00 0.00 2,433,936.29 317,473.83 0.00 0.00 200.00 0.00 0.00 200.00 20.90 0.00 0.00 2,433,936.29 317,473.83 0.00 0.00 300.00 0.00 0.00 300.00 120.90 0.00 0.00 2,433,936.29 317,473.83 0.00 0.00 400.00 0.00 0.00 400.00 220.90 0.00 0.00 2,433,936.29 317,473.83 0.00 0.00 500.00 0.00 0.00 500.00 320.90 0.00 0.00 2,433,936.29 317,473.83 0.00 0.00 600.00 0.00 0.00 600.00 420.90 0.00 0.00 2,433,936.29 317,473.83 0.00 0.00 700.00 0.00 0.00 700.00 520.90 0.00 0.00 2,433,936.29 317,473.83 0.00 0.00 800.00 0.00 0.00 800.00 620.90 0.00 0.00 2,433,936.29 317,473.83 0.00 0.00 900.00 0.00 0.00 900.00 720.90 0.00 0.00 2,433,936.29 317,473.83 0.00 0.00 1,000.00 0.00 0.00 1,000.00 820.90 0.00 0.00 2,433,936.29 317,473.83 0.00 0.00 1,100.00 0.00 0.00 1,100.00 920.90 0.00 0.00 2,433,936.29 317,473.83 0.00 0.00 1,200.00 0.00 0.00 1,200.00 1,020.90 0.00 0.00 2,433,936.29 317,473.83 0.00 0.00 1,300.00 0.00 0.00 1,300.00 1,120.90 0.00 0.00 2,433,936.29 317,473.83 0.00 0.00 1,400.00 0.00 0.00 1,400.00 1,220.90 0.00 0.00 2,433,936.29 317,473.83 0.00 0.00 1,500.00 0.00 0.00 1,500.00 1,320.90 0.00 0.00 2,433,936.29 317,473.83 0.00 0.00 1,600.00 0.00 0.00 1,600.00 1,420.90 0.00 0.00 2,433,936.29 317,473.83 0.00 0.00 1,700.00 0.00 0.00 1,700.00 1,520.90 0.00 0.00 2,433,936.29 317,473.83 0.00 0.00 1,800.00 0.00 0.00 1,800.00 1,620.90 0.00 0.00 2,433,936.29 317,473.83 0.00 0.00 1,900.00 0.00 0.00 1,900.00 1,720.90 0.00 0.00 2,433,936.29 317,473.83 0.00 0.00 2,000.00 0.00 0.00 2,000.00 1,820.90 0.00 0.00 2,433,936.29 317,473.83 0.00 0.00 Start Build 2.50 2,100.00 • 2.50 128.63 2,099.97 1,920.87 -1.36 1.70 2,433,934.90 317,475.51 2.50 2.17 2,200.00 5.00 128.63 2,199.75 2,020.65 -5.44 6.81 2,433,930.74 317,480.56 2.50 8.69 2,300.00 7.50 128.63 2,299.14 2,120.04 -12.24 15.32 2,433,923.81 317,488.96 2.50 19.53 2,400.00 10.00 128.63 2,397.97 2,218.87 -21.74 27.20 2,433,914.14 317,500.69 2.50 34.68 2,500.00 12.50 128.63 2,496.04 2,316.94 -33.91 42.44 2,433,901.72 317,515.74 2.50 54.11 2,600.00 15.00 128.63 2,593.17 2,414.07 -48.75 61.01 2,433,886.60 317,534.08 2.50 77.78 2,700.00 17.50 128.63 2,689.17 2,510.07 -66.22 82.87 2,433,868.80 317,555.66 2.50 105.65 2,800.00 20.00 128.63 2,783.85 2,604.75 -86.28 107.98 2,433,848.35 317,580.46 2.50 137.66 2,900.00 22.50 128.63 2,877.05 2,697.95 -108.90 136.29 2,433,825.29 317,608.42 2.50 173.75 3,000.00 25.00 128.63 2,968.57 2,789.47 -134.04 167.75 2,433,799.67 317,639.48 2.50 213.86 3,052.73 26.32 128.63 3,016.10 2,837.00 -148.30 185.59 2,433,785.14 317,657.10 2.50 236.61 SHALLOW GAS 3,100.00 27.50 128.63 3,058.25 2,879.15 -161.65 202.30 2,433,771.53 317,673.60 2.50 257.91 3,200.00 30.00 128.63 3,145.92 2,966.82 -191.67 239.87 2,433,740.93 317,710.71 2.50 305.81 3,268.93 31.72 128.63 3,205.09 3,025.99 -213.75 267.50 2,433,718.43 317,737.99 2.50 341.03 Start 3604.12 hold at 3268.93 MD 3,300.00 31.72 128.63 3,231.51 3,052.41 -223.94 280.26 2,433,708.03 317,750.59 0.00 357.30 3,400.00 31.72 128.63 3,316.57 3,137.47 -256.77 321.34 2,433,674.58 317,791.15 0.00 409.67 3,500.00 31.72 128.63 3,401.63 3,222.53 -289.59 362.41 2,433,641.12 317,831.72 0.00 462.04 9 5/8" 3,600.00 31.72 128.63 3,486.69 3,307.59 -322.42 403.49 2,433,607.67 317,872.28 0.00 514.41 3,700.00 31.72 128.63 3,571.75 3,392.65 -355.24 444.57 2,433,574.21 317,912.85 0.00 566.78 3,800.00 31.72 128.63 3,656.81 3,477.71 -388.07 485.65 2,433,540.75 317,953.41 0.00 619.15 7/10/2014 5:34:28PM Page 3 COMPASS 5000.1 Build 70 Halliburton -1ALL1 BURTON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 24 Company: Hilcorp Energy Company ND Reference: Plan:BCU 24 @ 179.10usft((160.5 GL+18.6 KB)) Project: Beaver Creek Unit MD Reference: Plan:BCU 24 @ 179.10usft((160.5 GL+18.6 KB)) Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 24 Survey Calculation Method: Minimum Curvature Wellbore: BCU 24 Design: BCU-24 wp2.0 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 3,562.77 3,900.00 31.72 128.63 3,741.87 3,562.77 -420.89 526.73 2,433,507.30 317,993.98 0.00 671.52 4,000.00 31.72 128.63 3,826.93 3,647.83 -453.71 567.81 2,433,473.84 318,034.54 0.00 723.90 4,100.00 31.72 128.63 3,911.99 3,732.89 -486.54 608.88 2,433,440.39 318,075.11 0.00 776.27 4,200.00 31.72 128.63 3,997.05 3,817.95 -519.36 649.96 2,433,406.93 318,115.67 0.00 828.64 4,300.00 31.72 128.63 4,082.11 3,903.01 -552.19 691.04 2,433,373.47 318,156.24 0.00 881.01 4,400.00 31.72 128.63 4,167.17 3,988.07 -585.01 732.12 2,433,340.02 318,196.81 0.00 933.38 4,500.00 31.72 128.63 4,252.23 4,073.13 -617.84 773.20 2,433,306.56 318,237.37 0.00 985.75 4,600.00 31.72 128.63 4,337.29 4,158.19 -650.66 814.27 2,433,273.10 318,277.94 0.00 1,038.12 4,700.00 31.72 128.63 4,422.35 4,243.25 -683.48 855.35 2,433,239.65 318,318.50 0.00 1,090.49 4,800.00 31.72 128.63 4,507.41 4,328.31 -716.31 896.43 2,433,206.19 318,359.07 0.00 1,142.86 4,900.00 31.72 128.63 4,592.47 4,413.37 -749.13 937.51 2,433,172.74 318,399.63 0.00 1,195.23 5,000.00 31.72 128.63 4,677.53 4,498.43 -781.96 978.59 2,433,139.28 318,440.20 0.00 1,247.60 5,100.00 31.72 128.63 4,762.59 4,583.49 -814.78 1,019.67 2,433,105.82 318,480.76 0.00 1,299.97 5,200.00 31.72 128.63 4,847.65 4,668.55 -847.60 1,060.74 2,433,072.37 318,521.33 0.00 1,352.34 5,300.00 31.72 128.63 4,932.71 4,753.61 -880.43 1,101.82 2,433,038.91 318,561.89 0.00 1,404.71 5,400.00 31.72 128.63 5,017.77 4,838.67 -913.25 1,142.90 2,433,005.46 318,602.46 0.00 1,457.08 5,447.42 31.72 128.63 5,058.10 4,879.00 -928.82 1,162.38 2,432,989.59 318,621.69 0.00 1,481.92 B2 5,500.00 31.72 128.63 5,102.82 4,923.72 -946.08 1,183.98 2,432,972.00 318,643.02 0.00 1,509.45 5,600.00 31.72 128.63 5,187.88 5,008.78 -978.90 1,225.06 2,432,938.54 318,683.59 0.00 1,561.82 5,671.97 31.72 128.63 5,249.10 5,070.00 -1,002.52 1,254.62 2,432,814.47 318,712.78 0.00 1,599.51 B4 5,700.00 31.72 128.63 5,272.94 5,093.84 -1,011.73 1,266.14 2,432,905.09 318,724.15 0.00 1,614.20 5,800.00 31.72 128.63 5,358.00 5,178.90 -1,044.55 1,307.21 2,432,871.63 318,764.72 0.00 1,666.57 5,900.00 31.72 128.63 5,443.06 5,263.96 -1,077.37 1,348.29 2,432,838.17 318,805.28 0.00 1,718.94 6,000.00 31.72 128.63 5,528.12 5,349.02 -1,110.20 1,389.37 2,432,804.72 318,845.85 0.00 1,771.31 6,100.00 31.72 128.63 5,613.18 5,434.08 -1,143.02 1,430.45 2,432,771.26 318,886.41 0.00 1,823.68 6,200.00 31.72 128.63 5,698.24 5,519.14 -1,175.85 1,471.53 2,432,737.81 318,926.98 0.00 1,876.05 6,300.00 31.72 128.63 5,783.30 5,604.20 -1,208.67 1,512.60 2,432,704.35 318,967.54 0.00 1,928.42 6,400.00 31.72 128.63 5,868.36 5,689.26 -1,241.50 1,553.68 2,432,670.89 319,008.11 0.00 1,980.79 6,500.00 31.72 128.63 5,953.42 5,774.32 -1,274.32 1,594.76 2,432,637.44 319,048.67 0.00 2,033.16 6,600.00 31.72 128.63 6,038.48 5,859.38 -1,307.14 1,635.84 2,432,603.98 319,089.24 0.00 2,085.53 6,634.82 31.72 128.63 6,068.10 5,889.00 -1,318.57 1,650.14 2,432,592.33 319,103.36 0.00 2,103.77 UBC3 6,700.00 31.72 128.63 6,123.54 5,944.44 -1,339.97 1,676.92 2,432,570.53 319,129.80 0.00 2,137.90 6,800.00 31.72 128.63 6,208.60 6,029.50 -1,372.79 1,718.00 2,432,537.07 319,170.37 0.00 2,190.27 6,873.06 31.72 128.63 6,270.74 6,091.64 -1,396.77 1,748.01 2,432,512.63 319,200.01 0.00 2,228.53 Start Drop-2.00 6,900.00 31.18 128.63 6,293.73 6,114.63 -1,405.55 1,758.99 2,432,503.68 319,210.85 2.00 2,242.54 7,000.00 29.18 128.63 6,380.16 6,201.06 -1,436.93 1,798.27 2,432,471.69 319,249.64 2.00 2,292.61 7,100.00 27.18 128.63 6,468.30 6,289.20 -1,466.42 1,835.16 2,432,441.64 319,286.07 2.00 2,339.65 7,200.00 25.18 128.63 6,558.04 6,378.94 -1,493.96 1,869.63 2,432,413.57 319,320.11 2.00 2,383.60 7,300.00 23.18 128.63 6,649.25 6,470.15 -1,519.53 1,901.64 2,432,387.50 319,351.72 2.00 2,424.40 7,400.00 21.18 128.63 6,741.85 6,562.75 -1,543.10 1,931.13 2,432,363.48 319,380.85 2.00 2,462.00 7,500.00 19.18 128.63 6,835.70 6,656.60 -1,564.64 1,958.09 2,432,341.53 319,407.46 2.00 2,496.37 7/10/2014 5:34:28PM Page 4 COMPASS 5000.1 Build 70 Halliburton HALLIBUR I ONI Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 24 Company: Hilcorp Energy Company TVD Reference: Plan:BCU 24 @ 179.1ousft((160.5 GL+18.6 KB)) Project: Beaver Creek Unit MD Reference: Plan:BCU 24 @ 179.10usft((160.5 GL+18.6 KB)) Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 24 Survey Calculation Method: Minimum Curvature Wellbore: BCU 24 Design: BCU-24 wp2.0 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-5 +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 6,751.60 7,600.00 17.18 128.63 6,930.70 6,751.60 -1,584.12 1,982.47 2,432,321.67 319,431.54 2.00 2,527.45 7,700.00 15.18 128.63 7,026.73 6,847.63 -1,601.52 2,004.24 2,432,303.94 319,453.04 2.00 2,555.21 7,800.00 13.18 128.63 7,123.68 6,944.58 -1,616.82 2,023.38 2,432,288.35 319,471.94 2.00 2,579.61 7,900.00 11.18 128.63 7,221.42 7,042.32 -1,629.99 2,039.87 2,432,274.92 319,488.23 2.00 2,600.63 7,943.44 10.32 128.63 7,264.10 7,085.00 -1,635.05 2,046.20 2,432,269.76 319,494.48 2.00 2,608.70 B18 8,000.00 9.18 128.63 7,319.84 7,140.74 -1,641.03 2,053.68 2,432,263.67 319,501.87 2.00 2,618.24 8,100.00 7.18 128.63 7,418.82 7,239.72 -1,649.92 2,064.80 2,432,254.61 319,512.85 2.00 2,632.42 8,200.00 5.18 128.63 7,518.23 7,339.13 -1,656.64 2,073.22 2,432,247.76 319,521.16 2.00 2,643.15 8,300.00 3.18 128.63 7,617.96 7,438.86 -1,661.19 2,078.92 2,432,243.11 319,526.79 2.00 2,650.42 8,400.00 1.18 128.63 7,717.88 7,538.78 -1,663.57 2,081.90 2,432,240.69 319,529.73 2.00 2,654.21 8,459.22 0.00 0.00 7,777.10 7,598.00 -1,663.96 2,082.38 2,432,240.30 319,530.20 2.00 2,654.82 Start 2348.80 hold at 8459.22 MD-B24 8,500.00 0.00 0.00 7,817.88 7,638.78 -1,663.96 2,082.38 2,432,240.30 319,530.20 0.00 2,654.82 8,600.00 0.00 0.00 7,917.88 7,738.78 -1,663.96 2,082.38 2,432,240.30 319,530.20 0.00 2,654.82 8,602.22 0.00 0.00 7,920.10 7,741.00 -1,663.96 2,082.38 2,432,240.30 319,530.20 0.00 2,654.82 B28B 8,700.00 0.00 0.00 8,017.88 7,838.78 -1,663.96 2,082.38 2,432,240.30 319,530.20 0.00 2,654.82 8,800.00 0.00 0.00 8,117.88 7,938.78 -1,663.96 2,082.38 2,432,240.30 319,530.20 0.00 2,654.82 8,880.22 0.00 0.00 8,198.10 8,019.00 -1,663.96 2,082.38 2,432,240.30 319,530.20 0.00 2,654.82 B30 8,900.00 0.00 0.00 8,217.88 8,038.78 -1,663.96 2,082.38 2,432,240.30 319,530.20 0.00 2,654.82 9,000.00 0.00 0.00 8,317.88 8,138.78 -1,663.96 2,082.38 2,432,240.30 319,530.20 0.00 2,654.82 9,100.00 0.00 0.00 8,417.88 8,238.78 -1,663.96 2,082.38 2,432,240.30 319,530.20 0.00 2,654.82 9,200.00 0.00 0.00 8,517.88 8,338.78 -1,663.96 2,082.38 2,432,240.30 319,530.20 0.00 2,654.82 9,300.00 0.00 0.00 8,617.88 8,438.78 -1,663.96 2,082.38 2,432,240.30 319,530.20 0.00 2,654.82 9,382.22 0.00 0.00 8,700.10 8,521.00 -1,663.96 2,082.38 2,432,240.30 319,530.20 0.00 2,654.82 Tyonek 9,400.00 0.00 0.00 8,717.88 8,538.78 -1,663.96 2,082.38 2,432,240.30 319,530.20 0.00 2,654.82 9,500.00 0.00 0.00 8,817.88 8,638.78 -1,663.96 2,082.38 2,432,240.30 319,530.20 0.00 2,654.82 9,600.00 0.00 0.00 8,917.88 8,738.78 -1,663.96 2,082.38 2,432,240.30 319,530.20 0.00 2,654.82 9,700.00 0.00 0.00 9,017.88 8,838.78 -1,663.96 2,082.38 2,432,240.30 319,530.20 0.00 2,654.82 9,800.00 0.00 0.00 9,117.88 8,938.78 -1,663.96 2,082.38 2,432,240.30 319,530.20 0.00 2,654.82 9,900.00 0.00 0.00 9,217.88 9,038.78 -1,663.96 2,082.38 2,432,240.30 319,530.20 0.00 2,654.82 10,000.00 0.00 0.00 9,317.88 9,138.78 -1,663.96 2,082.38 2,432,240.30 319,530.20 0.00 2,654.82 10,100.00 0.00 0.00 9,417.88 9,238.78 -1,663.96 2,082.38 2,432,240.30 319,530.20 0.00 2,654.82 10,200.00 0.00 0.00 9,517.88 9,338.78 -1,663.96 2,082.38 2,432,240.30 319,530.20 0.00 2,654.82 10,300.00 0.00 0.00 9,617.88 9,438.78 -1,663.96 2,082.38 2,432,240.30 319,530.20 0.00 2,654.82 10,400.00 0.00 0.00 9,717.88 9,538.78 -1,663.96 2,082.38 2,432,240.30 319,530.20 0.00 2,654.82 10,500.00 0.00 0.00 9,817.88 9,638.78 -1,663.96 2,082.38 2,432,240.30 319,530.20 0.00 2,654.82 10,600.00 0.00 0.00 9,917.88 9,738.78 -1,663.96 2,082.38 2,432,240.30 319,530.20 0.00 2,654.82 10,700.00 0.00 0.00 10,017.88 9,838.78 -1,663.96 2,082.38 2,432,240.30 319,530.20 0.00 2,654.82 • 10,808.02 0.00 0.00 10,125.90 • 9,946.80 • -1,663.96 2,082.38 2,432,240.30 319,530.20 0.00 2,654.82 TD at 10808.02-5 1/2" 7/10/2014 5:34:28PM Page 5 COMPASS 5000.1 Build 70 Halliburton ALL I B .. TON Standard Proposal Report Database: Sperry EDM-NORTH US+CANADA Local Co-ordinate Reference: Well Beaver CK Unit 24 Company: Hilcarp Energy Company TVD Reference: Plan:BCU 24 @ 179.10usft((160.5 GL+18.6 KB)) Project: Beaver Creek Unit MD Reference: Plan:BCU 24 @ 179.10usft((160.5 GL+18.6 KB)) Site: Beaver Creek Unit North Reference: True Well: Beaver CK Unit 24 Survey Calculation Method: Minimum Curvature Wellbore: BCU 24 Design: BCU-24 wp2.0 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) BCU 24 BHLTgt 0.00 0.00 10,125.90 -1,805.05 2,038.65 2,432,099.90 319,484.30 -plan misses target center by 147.71 usft at 10808.02usft MD(10125.90 TVD,-1663.96 N,2082.38 E) -Circle(radius 50.00) BCU 24 BHL Tgt wp2 0.00 0.00 10,125.90 -1,663.96 2,082.38 2,432,240.30 319,530.20 -plan hits target center -Circle(radius 50.00) BCU 24 Mid Tgtwp2 0.00 0.00 7,777.10 -1,663.96 2,082.38 2,432,240.30 319,530.20 -plan hits target center -Point 1 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (') 3,500.00 3,401.63 95/8" 9-5/8 12-1/4 10,808.02 10,125.90 5 1/2" 5-1/2 8-1/2 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (usft) (usft) Name Lithology (°) (1 8,602.22 7,920.10 B28B 5,447.42 5,058.10 B2 8,459.22 7,777.10 B24 7,943.44 7,264.10 B18 3,052.73 3,016.10 SHALLOW GAS 5,671.97 5,249.10 B4 6,634.82 6,068.10 UBC3 8,880.22 8,198.10 B30 9,382.22 8,700.10 Tyonek Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-5 +EI-W (usft) (usft) (usft) (usft) Comment 2,000.00 2,000.00 0.00 0.00 Start Build 2.50 3,268.93 3,205.09 -213.75 267.50 Start 3604.12 hold at 3268.93 MD 6,873.06 6,270.74 -1,396.77 1,748.01 Start Drop-2.00 8,459.22 7,777.10 -1,663.96 2,082.38 Start 2348.80 hold at 8459.22 MD 10,808.02 10,125.90 -1,663.96 2,082.38 TD at 10808.02 7/10/2014 5:34:28PM Page 6 COMPASS 5000.1 Build 70 z1 o3 H L m oc 0I 3 _ mo J J ` L IQ. N W 2.E 7 Ems 2c o e U C a1 a) q Q �' d aill u N - N N Q E, 3 H `o T 0 . ,,,i Q O C ICC/ ..-Ct N c w o X C0 y U o sa -7_,,-,.. A v m o � CL 13) L N ,- -O + 2 - N E C 5 rmmY •c at of m M w rO ® al O z ~ °; J co Df in Y m u, m c..1; ..1 a IIc W m r >}�,� 0 — VI O m a n d /L 0 f - o a) c J W t-_-' l LL O a{ M T LL i fn Y Z p-' H ar Q W ` > W ■7) E i N ' N U W E U t0 N ei O ■- •p > OM1 LL N Q m v m o 1 a o m o S. � � Y 0 L ca 0 " ` � m � N m O 1n O 0 0 0 ID L O R a w Q O -c-; �` N N o y io .. o w c '+ L L L ■� V w d 0 N N >, a 0 :o a m •2 uoi ai ui MMMI Cc co R > C ' _ ' = m m m m 0 o ii' 1:1o113 > �, �, —5-: mo nnnPl,n E i INN villiui' H,. iQ: .mar ;q AM , ni 1111 1110inyiinN111 ...11111M01, 116NI MN Gr l.l, ;iP a"NIIIIIIII idl'h liMIIIInIIII11111I 1111IIM'"u EN. 'Uri e0 t 3111 Mai , .nininnom:" lu . sit'issmskrom -TEX lilt, MPnII88,,,111111111111111111111111111111 INUNININEN. • - p NEM n a'0111111101111M11:' 'LIQ FAME M likiki a c c co c coQ a a o °.' C 0 � a o c N W GO CO. a en GO NNNN N N N N N N� N 0 N N N (0 N N N N N 0 N 0 0 0 0 0 COCCO (0 0 0 0 0 (0 (0030 (0 N030 (00303 CO (00000 00 (00 _ a a a a a a a a a a a a a a a a a a a a a a a a a a Cl_ a x C O L C C C C C C C C C N E 0) O O N O O m O O a) O O N O O N O O N O O N O O w O O m Co 7 O .� 5 O N U O .o o O .o o . ---„, -5' O i0 U O W t O N V O f0 ; O "ca E 0 (0 LL ((CO `O LL N `O3 LL N (0 LL (0 CO LL Cm CO LL C CO LL C C6 CO C (0 LL N C6 C N N a) N mC. m N m m m m m o m O3 w m O3 N ca m N CL m m W m m N E 0 � 0 � C 0 m C 0 m c 0 (00C0 c 0 � c 0 � c 0 C0 0 E m m (0 m m 6 N m N N m CO N m N m m 0 N m N m m (0 m m (0 m co C N (0a) C1N CdCN (O CNa0 CaCO Ca (0a) d CaNCN N - O m = O m0 m = O m = m m = m mO m - W m O m 0 W U O W 5 0 W U 0 W U 0 W U 0 W 6 0 W (7) 0 W U 0 _ U 0 N CD M CO CO OD 0) N r CD V N. CD N- O CO CO CO CO V N. a- CD CO 7 In CO N N- CO I,- CO 0) V C7) O) 0) O D) O) CD W n 6 CO LC) N 7 N. l7 W V () y CO (D O 7 V OD 7 7 M N- N- a- n N. m CO (0 ,- V r- CO CO Cr) CO CO r n CO C O 00 W (0) r O 7 O I- (D M N- O M O) O) N M N I` 6 O .- O CO V .- .- .- W CA N CO 7 .- O '' a- CD V' N. CO CO CO 7 a- a- a- NNININ W LL U N. 7 7 N O� N N. O CO CO n O 0) N. O 0) N CO C) N N. C) CO 0) O n CO O '0 N. CD 7 O CO M N. a- N CO V) 0) CO CO O M C) O CO N. CO O O) 0) O CO O O EL) 7 CO (Ni N M CO 7 V 7 W N 7 O) V V O� CO O 7 W CO N- O U) 3 L 7 CO CA .- co N4 N- CD N W 7 N O) N N N V N C` N O N C) CD (O O CO p. " CO CO O M '- CO CO V W .- 7 CO V a- O O 0) N N CO N CO m 0 a- a- N N CO O) 6666 V CD N CO I- CO N CO CO 7 CO CO 7 7 W N N N- N (O CO V CONCOM C W O) CO 7 CD CO I. V CO 7 N 7 V N O I,- CO (0 CD N- O) N .- W O) CO CO CO O CO 6W N M (D C` O 7 7 6 7 7 Ti N O V r r CO M M6 CO 7 W N (0 CO N- N N V CO CD 7 N- NOD P.- N.- a- 006 CO CO N 006 N N M N a` a- a- a- N N N a- a- CO ONINN a- a- a- a- a- a- a- O.'— W O N V) O N O 0 N C) O CD O O O O O O O V O O O O O C) O O O M O 0 M N 0 f� O O CO C) O CO O O O O O O O N O O O M O O O O O C) O O O EL) N. O O O) O O CO Cn CO CO O O CO O O CO CO CC) CD CO CO O CO CO N- O O N- aI > L CO CO O N CO O V I` N N O CO N O CO N N I` .-- I- N O N N O) O CO C) O) N a Com' CO CO a- M N CO CO V N W N N CO V a- O O O N CO Q. t6 m N N CO W N N N N m p p m aU N E A 'C O) CO CC) N 7 0) N. 0 CO O 00 CO N CO CO V CO CO N N N- N ii N COCO CO .- CO CO c' O CO COO) N- CO 0) CO N N 0)W II--- OD 0 CO CO 6 a- a- CO = E U O OM 7 M .- N N O CO CO O O M M D D O M M CD O O O N. N. O N N CO W CO CO r N- O N. N. N 0 0 7 O CO CD CD M M 7 M i NECy ._ ._ a- NNN c- c- O N .- N o c w o i o D CO a Vo COCO) N N O O N O O CD O O O O O O O 7 O O O O O O O O O CO O O CO Y O' CO '0 I� O O CO O O CO O C) O O O O C) CO O O O (O O O O O O O O O O a t12 .= r O O m O 7 vi Cri N ri O O Ui O O Cri Cri ri N Cri ri J Cn Cri r O O : ' CO• N yy CO CO ONCOO 7 N- NNOCO NOCONNN a- NNONN CO O CO0) ia it 2 vCOO 66 .- ,_ ,,,,i- MN 067 N O N CO N NOO V a- O O W N M re N N N N = = = a-- _ m c) CO 4-Iv m 2 L• N 9 co0 • N N L y ! 2 Y c t a,to y a 3 •w to 0 m tm c 0 CD 0 0 0 Zm CO 712. E m (aD COa3 3 3 0 L 4 . C• m CO CO z O O O M M M CD CD CO ) ) : N CO CO O 0) 0) N N N co 0CO 0 0 0 O �+ C DDDDDD DDDDDD CO m m D D D D D 7 D 7 D co co co ,, C 'C ` 0 U U U U U U 0 0 0 0 0 0 , C C 0 0 0 0 0 0 0 0 0 7 m _a CO m CO m m m CO CO CO CO CO CO 0 0 0 m m m m m m CO m CO 0001 m v u) 2 ..• CY CC Y 0 V O O O O ,- ,- ,- CO M MO CO CD CD CD (CO CO CO CO W 0) O) CO M M CO CO CO 0 <f LL Q N CV a- a- N N N E 5 O 7 = D D D D DDDDDD DDDDDD DDDDDD M M M M ' a = m. ' 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 LL x y o ' E c m m m m m m m m m m m m m m m m m m m m m m m m 0 0 0 0 v M = a d O m Z = 0 0 0 (n (n (h CO CD CO (o CO CO 0o co m CO CO 0) CO CO CO m m m m o Wm Y ao y Y . . . . . . a- a- c- a- a- a- .- a- NIN N COCOCOM N Om C O N d C C C C C C C C C C C C C C C C C C C C C C C C C C C C j JCO m• m O C - D D D D ) D DDD DDDDDD DDDDDD DDDD E a) N E U 0 0 0 0 0 0 000000 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 NO J 0 a 0 CO - 10 `m ` ` ` a > 0) a) 0) 0)) a) m m m m m m 0 ` ` `m a a a ` 0)) a) ` ` ZQ awCC C CO CO dii E ea > > > > > > > > > > > > > > > > > > > > > > > > > mdN N 0 N 0 N 00 0 N 0 0 0 0 N N N N N CO N N 00 0 (000 .. o m m m m m m m m m m m m m m m m m a) m m m m m m m m m m_Q o A A U .1Z' o nfii0 m mmmmmm mmmmmm mmmmmm mmmmmm mmmm C• 'a CO CI CO c. 8 C) E j . o E 0 U 1 >o C ro — C C) eta Lz7 CO C. O. r0 Q N CO N CO N N N CO N CO N CO CO CO Ca co co co N co co N N (0 N co co N N N (0 N O) CO (0 CO (0 N N CO CO CO (0 a a. a O a a a LL LL O O a a O c 0 v m E 4 `O p 4 `O m e `o d c°- `o y c `O (a 7 .CO E � U U 'N U U .� U O .� . U .� U 2 2 a LL (0 a LL (O a LL N a LL N a LL E (0 c ❑ 83 c ❑ .(13 63 c ❑ (% c 0) l0 N 0) W N g,"2 N 0) N N 0) N O N N N N O fA O_ co C d N C (2 N C Q N C (1 N F 0) W N W 0) W 0) - a) w U U w U U w U U w U U w U rn m co CO N N N N CO O V V N 7 2 N 0) V) (f) V V) V) V CO Cr V N 0 0 (i) + + U I- r 0) CO V) 0) CO (f) 1,... CO N O CO CO U U c O „.-1. O 6) 6) 6) 6) O (P (b N (O (n (n N N + + N LI- 0 ❑ ❑ U N- CO V V) V) V V) V) O s- V) V O CO -a co (O N N CO N N CO O W (0 V N CO i 1` O N V) VN V ) V) V) O V 6) I� M M 7 .0 O V) O N N- 0 N N. 0 N W V U) V $ N CO 0 0 s- 0 0 s- 0 0 r- CO (a y W s- s- CVCVCVCVCVCVN N CVs- s- s- o 0 V N CO CO N. N. (O N- N- CN N. M O CV C 6) CO N ) N V) COM COM M r N- y 0 O V N N (O N N (O O6 r 6) W N N a- CO V) (n a- V) V) V) a- N. m rn a ( y W .9. CO 4- O 0 0 N- 0 0 I 0 0 0 0 0 0 0 0 M -a 0 0 )- 0 0 0 0 0 0 0 0 0 O O N V) V) N V) V) O V) O d' O O C 0) 7 .0 O N O N I- O N N- O N O Z1. V) V) (a a) y Q y N CO O O O O O O N M LL a N ) V — s- N N N N N N N N N s- s- s- N 2�(U N V 7 N E co N I0 r CO O I”- CO O 6) N 6) 6) O N C( C s- CO N M CA N M 6) M (O N M N 3 = E a) ((i 6i O) N ) N 7 2M V (0 co (0 CO(O N. CO CO 0)) 0 0 (z N c E C N O C co 7 O I co 0 m A 0. co0- ° MU _ oN (n O O N. 0 0 N- 0 0 0 0 0 0 0 0 0 0 0) W c a. y 'a 3 N 0 0 0 0 0 0 0 0 0 0 0 O N V) V) N V) V) O V) O V O O N N p- d yo _ I N` V E' ` t $ O V) 0 N N. 0 N r O N O VVV3 3 6 = N — 7 0. y NM O O s- O O s- O O N M V V O Wi W N c, s- s- N N N N N N N N N s- r s- N N C . -p 4.1 73 H m m m3) o E E s v a) N y .8 LL N ((5(a 0o E o o 3 Wm C C C.) O• 4 = Nv o o p_ d m U >,. CV FVCO L '' oCO O N U j7tp ca) (U -2 0' E N Q 7 y N •CN OVN V o C ❑4) O • d N 0 ZW�L o aNLL E ❑ ❑ (5 LL2 ❑ ❑ ❑ CC K LLw N d "O N .L O O 0 W co )(Oo2 - w O1.1 cmA y O 01 O � cc ` Z M M VV) V) NUD O (n an in O D U m m m rn co rnG 14. E $ O O N 0) C m= d '3 o N :o9r. � N e -O F. L V = y C 'at v mm mmm > > > U U U U U U U U U Z ❑ ❑ m CO m ❑ ❑ ❑ m m m CO CO CO o 3 N V a , mQ c 3 �) n n n a0) mmm 0) 0) rn a mJ pd 24) E V cc; d DDD7D D > > > > D D > > Tii 22yy ( re G do 3 E 00000 U U U U U U U U U m m m m m m m m m m m m m m y 1, p � N R MLLas G v 01 Q M r d V) V) co co O m O O ..0 C C C C C C .0 C C C C C C m 3 m 112 C ❑ N 0 U o 0N MEM .= .c C o N NN (0 c II 10 j J •y U 'OO C DDDDDDDDDDD DDD E N O O O - y YYYYY YYY CC N y oN — O O E m 00000 000000 000 0 Nuel 0 Oy Z 0. N N > 0) N U) U) UN N N N U) 0 O ONmp -p c Q VQ asc O < W C R > > > > > > >E m m m m m m m m m m m m m at 000 000000 0) 0) N N N 2p UCO O l6 _ ^ 0 No w A A a U N O U m m m CO CO CO CO CO m m m m m m N 7O0 0 l o d l6 N 0 co 0 w 0 < o c R , ad N Vj q O O U > pp$. C ca _O > CO CO U CO CO CO O CO O � O C) D > D W W > > D m > > 6 ch U Lo U (o rn L) O O O p O O U J m J m J D C. m m m m cc m m m v p a oa- .= ri m ao ai c6 m Et m ct m m `1 LLJ 03 0Uc 03 03 m pip COM C" ° ° ° ° 0 O (o (o ao of (vi m m m m m m W N r - • r ,2 r J 5 5 5 5 5 5 5 5 5 5 5 5 5 5 N y g- 9 9 9 99 9 9 9 9 9 N m CO as ea as m m a) m at CO CO CO CO a) a) a) m m m m a) a) a) a) a) a) a) CO m CO mmmmmm m m CO m m m I I I I I - ---- 1 I I 1 11/ I I -I 0 O N .� to I I -- — Q i fI I I I O Y 7 Q I I I I I I 414 m -- ----�'�It, 1 I I _ co m rj1jj//.4 I I p a ar I I a) '� I I O o) > I .l I I O 0 m I Al I I I O ` I I I a O N I / I I I `m I .1 I I Q w I 11 I -- °- I `-- --- - _.I__ 1.4 N t0 O 1 a `/ CD c N ° *� ba1\�\ i ►�A 1 ,� N °° •� �,•,,. it —o rMfo Z fl I :. \. Q W ��-V 1311lj�e o 0w a .%;,174, S N 0 I m a 1 • c fr;'�( v �y owlLL m j u) o I I I1 �.iI W c a) a) ni O O N. ° mN o O d ON � c CD 0 J — N N oo Qc o co (uvi}sn ppb) uoiieJedas ailuao 01 aquao T Q ) a 0) 6 3 3 8 a c e a x E a) O U 0 0 0 R > O O y N > > U.• > > > > > `'- > > 5CCCe 0 CO CO O) O C') O U) O O W C.) CO > 0 > 0 > > > > > > m > > co U cn U m a)L COCOCOCOctCOCOoUmUmV m ctctU 00 of ca 0 co. Oi co m m m m a C.J N M CO 47 la CO O) W 0000000 a > > > > > > 0 m m m m m m m m0 ° 0 ° 0 ° 0 m CO CO m W O M CO O co- O N C M In LO CO O) J •c 'C •C •C 'C •C •C •C 'C 'C 'C 'C 'C 'C O DDDDDOODDDDDnDOI U U U UUUUUUUU U I'' RRRRRRRRR RS' co () CO co cu f6 CO CO CO CO CO fO CO 0) a) a) a) a) Cl) a) a) a) a) a) a) a) N a) U Co 00 00 [O 03 CO CO CO CO CO CO M CO CO CO X44 + * 4 + + * + + + 4' • o — -4- .-....... _..__..._......._ o N • _... ... .... {..... -._...._ 0 .._._ _._—.. —....._ ..__ o • •---. j_. _.-.. ._._. •• .-. � .. _ O • 0 —O O • • . '., _ m • N m c. —o N d • U a) I D c U •Tr D C CNIO L J .._.. _ ........ ........ ,o N . - o '412 O a) • -- -—O 0M Z 03 Et ED 0 Ofll — o y. J U cn ca co O a) O> YO • C N O t. O C ' m a • O O N U O o - ; MIN O U Z - LL II l I l l l l l l l l l l l I II O O cn .O U 0 IMI O r- N O r O o N 0 LC) (N 0 Q 0 V C O N N- c0 N) CV O I (u!/09.Z) Jo}oed uo}eJede < U Surface Use Plan Beaver Creek Unit Well BCU 24 Surface Location Anticipated: 1656' FWL, 1246' FNL, Section 34, T7N, R10W, SM AK Existing Road: The proposed BCU 24 is within the unit boundaries of the Beaver Creek Unit. The roads in the field are suitable for transportation of the drilling rig and support equipment. The road leading into Beaver Creek Unit is partially within the boundaries of the Kenai National Wildlife Refuge and is also suitable for rig transport. Kenai, Alaska is the nearest town to the site and is approximately 10 miles west of the proposed well site. A map showing the location of the proposed well site and access route to the site is included in Figure 1. New or Constructed Access Roads: There will be no new roads or road upgrades required for the drilling of this well. BCU Pad 3 will not need any expansion to accommodate the drilling rig. Location of Existing Wells: BCU 24 will be drilled from the existing BCU Pad 3. A map showing all known wells within a one-mile radius of the proposed BCU 24 is included in Figure 2. Location of Existing and/or Proposed Production Facilities: Proposed new well BCU 24 will require the addition of production facilities on Pad 3. All facility work will be on the pad and will be permitted under a separate sundry notice. Location and Types of Water Supply: Existing Alaska Department of Natural Resources permitted water sources in Beaver Creek Unit will be utilized to support drilling operations. All water use will be tracked in compliance with applicable permits. Water will be transported via vacuum truck from water wells to the rig location. Potable water to supply office trailers on location will be hauled from an approved water sources outside the field. Construction Materials: No road upgrades will be needed to allow for rig access. Gravel hauled from outside the field or from in-field stockpiles will be used to level the pad if needed. Methods for Handling Waste: Drilling muds and cuttings: Excess mud and cuttings will be hauled from the rig pit system to the Kenai Gas Field Grind and Inject facility. Wastes will be disposed of in AOGCC approved well KU 12-17. If this disposal option becomes unavailable, drilling cuttings will be hauled to approved waste disposal contractor Emerald in Kenai. Brines & Completion Fluids: Eligible fluids will be hauled to a permitted Class II disposal well in the Kenai Gas Field for disposal. If this disposal option becomes unavailable, drilling cuttings will be hauled to approved waste disposal contractor Emerald in Kenai. Garbage: All household and approved industrial garbage will be segregated and transported to the Kenai Borough Central Peninsula Landfill for disposal. Beaver Creek does burn a small volume of oily sorbents in a Smart Ash burner in field. This will be utilized as available for drilling operations. Chemicals: Unused chemicals will be returned to vendors or utilized in future operations. Sewage: All sanitary waste will be contained on-site and hauled off-site by a designated contractor. Ancillary Facilities: A trailer will be staged on the pad to house various supervisory personnel and a minimum number of support personnel. The remainder of the drilling crew will be housed in the Kenai area and transported to the location in a crew van. Due to space constraints on the drill site, some rig support equipment will be temporarily staged at nearby pads within Beaver Creek Unit. Equipment and materials including but not limited to dry mud product, cementing equipment, support vehicles (vac trucks), and rig components may be staged on BCU Pad 4 or Pad 1A. Some rig equipment may remain staged at Pad 32-33 in the Swanson River Field. Spill Prevention: The drilling activities are conducted in accordance with state and federal spill prevention and contingency plans. Spill prevention practices such as daily visual inspections of tanks, lines, and secondary containment areas, certified inspections of regulated tanks, and spill prevention and response training for personnel are conducted for all drilling operations. All liquid mud product drums will stored at the drill site in a lined, bermed secondary containment area and will be visually inspected on a daily basis. Spill response materials such as sorbents and oily waste bags are available on location at all times. Well Site Layout: There will be no reserve pit on location. A plan view layout of the Saxon Rig 169 is provided in Figure 3. Plans for Surface Reclamation: Access will be on existing roads within the Beaver Creek Unit and the well will be drilled from an existing pad. Approval for final abandonment of the well and location will be obtained from the BLM and U.S. Fish and Wildlife Service prior to any reclamation work. Surface Ownership: The surface lands of the Beaver Creek Unit and the roads leading into the field are within the Kenai National Wildlife Refuge, and are managed by the U.S. Fish and Wildlife Service. Other Information: The Saxon Rig 169 will be used to drill the well. A plan view layout of the rig is provided in Figure 3. . 1 34 114111111131111 36 =Mk 34 35 36 31 32 33 0000 2 0UU� 2 (1 r 4 3 0000000010 0 7 0010 1�►,1),(I�✓.,' o t0 Emma 17 16 1 15 14 18 17 16 15�(�-`)�y�r,3 17 16 15 14 ® 18 17 16 1 S009N010W —S009N009W�;� li S009N008W mi 20 21 22 23 24 19 20 21�� 20 21 22 23 19 20 21 22 30 000® 25 30 1.1 .-.2-111111 m® 30 00 0 35 m0000® 36 31,e ®m m 32 END 31 0® 00000000 2. 1 6 �' l �©00111#d11000 1� C0619 Land Stats 8 WAN ■..r R 0 7 Q 1 NIDI alKenai National Refuge Boundary 11' 15 14 13 18 17ri 15 14 13 18 17 • 15 14 m 18 17 '� 15 `,' ' ` " 18 Om sr 111111 S008N010W S008N009W ®0 S008N008W 1 22 23 24, 19 � 22 23 24 19 20 21 ?i, 23 20 21 22 23 24 19 20 0657 r:2'm 25, 30 O00®® 30 OF••''. 1® 30 0®m"® 30 Om �0 35 I 36 11111111111111111 •31 .Si\�31J' 'ig ®=0® ®®® sp..2/, I 15 5 4 `\3 (- 2 I - 6 74 mra�u �©©m 6 ©m 9 ,o „ 12 7 8 Locawell BCU 24osed ■ �j►10000 ,p 0 12 7 El mr I 15 14 13 17 16 Mil 7 - 15 14 li m17 16 15 14 13 18 17 16 S007N011 W SO17N010W S007N009W 0 S007N008W S007N007W r 22 23 24 19 20 21 22 23 • 1• 20 1 2 20 21 22 23 24 19 20 21 1 21 27 26 25 30 29 Loil, 27 26 ' 3• • -mmm0 30 ■O0® 25 0 28 saLlaa.,. - 34 Om 1 i 32 OmDD 0000Om 00 D � ©Ov©0Q©OO©0©00000 m ll m0000 10 SIM 1111111111 10 00000 16 15 14 13 18 17 16 5 14 13 MEI1615 -`10 17 16 15 14 13 18 17 16 I S006N011 W --S006N010W I■ S006N009■T■■W.1[[� imi NI S006N008W S006N007W I 1 22 23 24 20 21. .. .. .. ,"■ S 21F O R K... 21 22 23 24 19 20 21 ■ �0626 0I!® 10®0 30 0 28 0.6 0UEI000® 30 DI I.ziono�ER ®®0035 m�■m0� 31�1{7fY -- Witii 00 IN_--._. iihm..HEE©2 sed 4 I. 3 2 1.06 11.YYS__ I 1 11111161 0 m 9 10 12 7 �ll�ml�l' Q 7 8 9 10 11 12MEI S005N010W 7,:i.,„' Fit —T 7�� ��� 15 14 13 �� 15 1 14 I ,317 I6 15 �TE�L•INC 16 Imo--RI;---.±N—Gimme Hi r•hwa� 6 S005N011 W- 21 ■■ .'r S005N009W di S005N008W S005N007W 22 123 24 iQ- - - -22i 23 24 m 20 21 22 23 20 21 22 23 19 20 21 mom 30 100���m0®000 30 0®00 30 DI 35, 36 31 r OLDQTNA 3132 33 34 35 36 31 32 33 34 35 'i6 '11 '12 "1'1 Legend 4 3 2 1 /6 5 4 3 2 111 5 4 3 2 1 6 5 4 3 Gas Fields 0150 m000 000 —S004N00 Ga Fields ' 10 8 10 11 10 g g ,p —Gas Pipeline -Mulli.Product Pipeline 16 1 15 14 ,13 00 16 15 14 13 18 17 16 15 0 CM -Oil Pipeline S004N011W S004N010W S004N009W "ilcorp G6GDnta 21 22 ,3 24 20 21 22 23 24 19 20 21 22 23 Kenai National Reluge Boundary ■ Facilities Ingi ® ■ Gas Storage 2fi 3D •29 28 27 26 25 30 29 28 27 26 —Major Roads 33 3• • , a Cook Inlet, Alaska II 5 2.5 o KNWR Boudary 1 1 FEBRUARY 2013 Miles • 0 62,,0, I W B07 72 F00,1. T , I . • BCU 24 SHL ' C6O,�_-4, Proposed Location..)" -.' -' +Bcuoa .1.4-0.11E)3773 \ '.. C i '..- ., BEAVER 'ZIRt - (-)( 3 - • , 1 } ` 3G2-P,UD3 '%..1 44." a BEUIThI , --+- -_BCU 14'BCU 15. et,,e)''\ BCU 0IABCU 14A d o r1 : a�,e,to`eC 1\ BCU 102,�.. cCUj0T (Project Area's,. BEAVER CREEK UNIT - - —._ Legend Pipeline Beaver Creek Pad 3 N 1 inch=1,250 feet A tui,nr�ai..1..ta.c BCU 24 Proposed Location Buffer Map Date:03/2014 - - Surface Well Locations One Mile Radius0 1,000 2,000 3,000Feel 6 • ,::�One Mile Radius Buffer r I 9------e ) e III g s g U ui � N,I, /, 1 ° 111 NE!!IIIiso „°_,.,,, ..... . I I I ... ._ Iplllllllll;j 1 !:8. KQ�111111IIPI''J'JII11 1�I'II 111/1111 �����{��I�I�CI1. II'I IIIIIII'll'I'III, _ 3 I 1i' i, iIIIi;!1i 11 I ,I III I1 I zig 1 3 qq 4 gg p9 ll� Ili . $ I. IT g i l �b illi id i .I �IIII it � ��li ill �Illl 1 JiIi l JIIII li, _ _'ilill'illlili ilI Ailiithilililll l, Iii11 11411 I I I I I 11imIII IniilI II: ink flm a �_.. M. 111 MI Z1.= 1 . - 1_1 1'1 �!, 1 ... L, Pl1 III„5,1__1 , - ms,_ I I II I r� �� L; i I1"11II '��, 1,11 I III1I �t�.�t 0� i �� .1 j w III � ' p ' � .� `VIII■uIsI — '° - firllfal�� & Z III_■I■�■I!I � ai A'� ;I o �I R IIS_ II it —i 8 = o CI, i c it -�I x I I2 ' 3 X681 cd _ hl ij 1'! I ; I how— I111211.11i i 'IMF__ auiiiiiiTOTii _ -,i►.jIIt, ""'1,1 - FF1 Ol/rii Off! i Ip I :'�III= _, _ r1 m 1 = iii IMM!VEIN 61i.IMM _i--r-r-o �. -, 11110 741 io ° I 7110© Tt'oo'� r:i 0 ° Iii 1 I II v ol ®z t 'ri (r Y ` .Sits 2 li tl Zr �V 0 mi r 7 E * m . z 9 Z o Q , m VII i;=--)l� 1 ., Q O U in ,I e a a aI_01 1.1 ° ilRil l 6 2* ❑ °(;I 8 o a d a uV o - _ -- 8 .6 -.9- •t-,u S .9-,u .z-z .9 .+-z .�-.z�-�.z-,+-�z� � .9-.61 - 8 • g 3 w iw N Davies, Stephen F (DOA) From: Monty Myers <mmyers@hilcorp.com> Sent: Tuesday, July 22, 2014 1:51 PM To: Davies, Stephen F (DOA) Cc: Jeff Allen;John Serbeck Subject: RE: BC 24 (PTD #214-112) Permit to Drill Application: Questions Steve, Sorry it took me so long to reply. Been in meetings all day today. The shallow gas that is stated on the geoprog should not pose a drilling hazard for drilling the BC#23 or#24. We have drilled through this zone most recently with Saxon 169 on BC#7A and didn't see anything that would raise a red flag. There may be some gas there but it is normal pressured and poses no risk to safety or environment. I included our geologist and reservoir engineer on this email for comment. Do you guys have any concern about the shallow gas, or can you answer Steve's question with more detail? Thanks! 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: Monday, July 21, 2014 5:49 PM To: Monty Myers Subject: BC 24 (PTD #214-112) Permit to Drill Application: Questions Monty, The Geo-Prog on page 42 of the supporting documents for Hilcorp's Permit to Drill application lists"Shallow Gas" as an anticipated formation top in the Sterling Formation at 3016'TVD, which is above Hilcorp's planned surface casing point. Can you tell me what this "Shallow Gas" marker is, and whether or not it constitutes a drilling hazard? Thanks, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7`h Avenue,Suite 100 Anchorage,AK 99501 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If 1 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME: PTD: l( /Development Service Exploratory _Stratigraphic Test _Non-Conventional FIELD: e POOL: ,gx. -E'" _ 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 MC 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 Well Lo ,n also required for this well: gg g Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 MC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 4/2014 U) U) 0) 0 U) u) a) 0 coE _ 7 ° C E Q 'X n @ a) a• ) E @• co O u) m UO c ° O d w aa)) n ai o a) C O C N a) o (D a) u) w L 0 W co 0) '@o a > O 7 p a a) -O O Q m �° a) a) 7 0@ r c E n E 0 co - @ N -0 O 0 coa a N n @ 0 L = °- U6 ,- CD OU c x o 3 o E o Q) a) c U a CL CD0 *-0. - _c O 0) O L a) m C a -a to C a) E E .- u) O > 3 0 N o -.. ,_ N 0 Y Q = Up a coO 0 C 0 a 7 m o L -@o ° 7 - ° E C O >> O 0 .� O 0 p o m �@ co > LO. @ co @ O c U 0 C)D 19 ° a n o .N E o 0 0 _ E n o a co ._ co = ' - W m -.--- , ° w o J $ @ 3 a) o >0 ui E 0) o -0 0 ✓ 0 a 3 3 o `o N L n o ° aci N a )) 0 CY) a) 0 0_ CC) ° V N a) 'U co • 3 -c ac) -° 0 0 co co W 0 N co m W Cal @ c E o o c 0° .N W O C a) a N W 0 C u) a)) c a) . 0" a m COO 3 -00 •°: O o @ _a >. E a) aai a) o m w c II CO LU CO o - w 0 a) M m > O J- ` n C N 3 a) = O > II n - 01 C 0 N Q N O m ° 3 O) L L Q a s N p E C = @ 2 u- W a) L L N co 0) 0) n 'n C r (O 0 "� 3 E N Q C et -0N3 omc � a) 3c = o ,- p n 000 � O a°) - 0 - > = ) 0 N N "a ) 'O @ co U6 o N x 0 E O- m (3 =a) w r o_ C -0 t 0 o) > u) 0 > v7 E @ w -o 0 � c 7 a) c N o L u o o a m ° Z `) > 0 :t O 'O 0 O n@ N E C 0 c a C cc 0 0 N• 0 - Q 0 C U /b U L x0 X ° U) U) C C O. @ In to O) @ Q N N CO @ W w LU H w 0 C- CD u7 u) m L U) a U) 2 (O 2 I I d a aa)) a w 0 Q aa)) a s a)) 0 a a a)) a s a)) a a)) a a)) a) aa)) 0 aa)) a) Q Q Q Q a) a s a)) a) a s a)) a) a a)) 0 Q a) a) a) a a)) a) a) aa)) o Q a s N) a) Q Q Q a Z >- >- >- >- >- >- >- >- >- >- >- >- Z Z Z Z >- >- >- >- >- >- >- Z >- >- >- >- >- >-. >- z z >- >- Z Z Z >, H O a) v) a N U T Q CO U u) o c @ o m •P E 3 - E a) O 0 0 C O a) co C O o 0 .4 - aI 0 A7 �- C L o a E O k ° c >, U so 0 0 0 E 3 0 O '0 N co O 0 co U 0 0 C _ a) Z o C '� co a) U6 Q 3 - 0 > E v) C7 i o u°)) u) Q m o E Q a �° o N ° _ n m o LL rX C - v J 7 0 \ 2 > c _ 7 n co Crc a v7 w Q uJ L_ '0 O- .� a) O Q N U co ° i ! I • o ° 5 o M o O 7 h ° 02 CL _ L.. 0 4 7 0 Lo 2 Z N @ 7 3 O U) c 0) L C U) 7 Q 7 < N V) a) a) 0) O 0 0 C -0 0 a) c -° `° N ° 00 a) CO O >) a)0- 2n Cl- N c C 0 C 0‘-- S N CC E E - a c C E UO o O M C C N - -C O otS 0 C 0 L n N L n C u) 3 U w @ c ° o W O O "� "O O N 0 17) c Q O ° CT 7 C) 'Q L n a) U O N a O S) 3 O > >' .N Q _0 o a) a) ••- c o c c ° o@ .. o o 0 o a) @ o o@@ Q m n o rn o 7x>" C u� w U E n 0 0 o r o o o c c 2 m - m n ° o E 3 a`) o L m 3 ,. a) E m m 7 a 0 0 0@ 16 0 L L L @@ -7o E aa) u ` E C a) u) M m 'N s ar) o V) o n 3 o .c o >, 3 c)E o < C O N N - a n is '3 3 aa) E a) .. o -° y .° - 3@ a) c) a a) on a .- o as ° 3 o s 0 ° W U O Y On -0 C a a C>6 o a) a a a O coE O C O a) O O C 0- O V N '°0 0 co n 0 01 c "0 - V) a < -o 0 a) @ o a) a) _ a) o E o E L o a) C us L n o m c n rn a) a 7n Co a L a0i o 0- 00 m m a@ m E m o .3 N N o o c t -0 0@ E o o@ @ n .N _ @ E ° 0 0@ ° @ �° o >, ' a 2 c u) 0 o a n a a) • _ a a) ii II m .0 - a a a 0 .N 0 -0 -0 -o C aai . in 7 a 0 > ) co - m aa) ° .. N o 8 ° 00 a c m a E 0 0 @ o L c C a) 0 c @ a 1:,), O U) = 3 "a p N 'C O s) C a) C �_J a E 3 7 > @ ' a) - . ° 2 @ 8 0 @ 8 c 1 L. �i) OU w c 0 0 0 0 aci m o `o 0 o a) O N ao c o 0 o o = a Uo -o m r ui °- E .3 N c 0 a v J 0 7 O O O .0 .� N U6 a. O a) p_ o a @ > > 3 0 , a) O ° W w a) ` a) L n E ) -� J i .2 ° g- - - - E a) a) a) E E C - 3 c C t F F F 'm a) a) > = a a o 0 E m w @ c @ T a .E m a .. 7 a n n a) a) @ a) - 2 0 0 7 2 2 @ -0 @ -0 = O O L ° N a) a) m 'a) a) o 0 G O @ a J 0 5 5 5 (n 0 0 a a 0 5 ¢ a z U U) U U U 0 Q Q " O m (0 U E2 a 0 cn u) U '% LU n O N M V IO O r CO O O ,-- N M .<5.,r to O r W 0) O M V LA (0 r U) O f I 0 N CO R LU c0 r CO 0) c) N N- °° 0) N N N N N N N N N N M M cc's', C) C) C) C) C) C'•) C') I~ UC V V co c CH a) G- p C - coas - N w N U O Q N 0) Q N Q N O Ca)n W O. V Iy r c r r 0 E ,, N w Q I•£ a 0 0) a -°o a 0 0 5 a Q Q U) w` a U) 0 `� (n Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify 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: Beaver Creek Rig: Saxon 169 Date: October 15, 2014 Surface Data Logging End of Well Report Beaver Creek Unit 24 TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Days vs. Depth 4. After Action Review 5. Formation Tops 6. Show Reports 7. Sample Transmittal 8. Mud Record 9. Bit Record 10. Morning Reports 11. 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: Beaver Creek Unit 24 Field: Beaver Creek Borough: Kenai Peninsula Borough State: Alaska Country: United States API Number: 50-133-20639-00-00 Sperry Job Number: AK-AM-0091663907 Job Start Date: 21 September 2014 Spud Date: 22 September 2014 Total Depth: 11300’ MD, 10698’ TVD North Reference: True Declination: 16.928° Dip Angle: 73.634° Total Field Strength: 55442 nT Date of Magnetic Data: 20 September 2014 Wellhead Coordinates N: North 60° 39’ 30.871” Wellhead Coordinates W: West 151° 1’ 2.842“ Drill Floor Elevation 178.18’ Ground Elevation: 160.18’ Permanent Datum: Mean Sea Level SDL Engineers: Craig Amos, Jane Grundin, Jacob Hansen, Jeremy Tiegs SDL Sample Catchers: Tristan Mullen, Craig Pence Company Geologist: John Serbeck Company Representatives: Rance Pederson, Joe Grubb, Jimmy Greco, James Sweetsir 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 9/22 - 9/24 12.25” 3200’ 2945’ 9.3 28.47° 9.625” 3186’ 2932’ 9/28 – 10/9 8.5” 11300’ 10698’ 10.1 0.95° 5.5” - - DAILY SUMMARY 09/21/2014 SDL arrived on location, warmed up unit, began rigging up, calibrated gas equipment. 09/22/2014 Finished rigging up. Spudded well, drilled from 70’ MD to 181’ MD and lost returns. Gained returns and drilled ahead to 345’ MD and circulated. Pulled out of hole to pick up directional tools. Making up BHA and running into hole at time of report. Gas: No gas was seen while drilling. Fluids: 84 barrels of water-based mud lost down-hole. 09/23/2014 Ran in hole to bottom and began drilling. Drilled from 350’ MD to 1,500’ MD, encountering clay formation. Circulated and short tripped out to 340’ MD. Tripped in to 1,500’ MD and pumped sweep. Returned to drilling, currently drilling ahead at time of report. Gas: The maximum formation gas was 22 units at 1479’ MD, there was no significant connection or trip gas. Fluids: 0 barrels of water-based mud lost down hole. 09/24/2014 Drilled ahead from 1,690’ MD to 3,200’ MD. Pumped sweep and begin short trip. Unable to pull on elevators, washed and reamed to 2,200’ MD, pulled on elevators to 1,500’ MD. Pumped sweep, circulating bottoms up at time of report. Gas: The maximum formation gas was 163 units seen at 2,431’ MD, the maximum connection gas was 163 units seen at 2,336’ MD, and the maximum trip gas was 57 units at 3194’ MD. Fluids: 0 barrels of water-based mud lost down hole. 09/25/2014 Circulating bottoms up, tripped out of hole to surface. Lay down BHA and rig up to run casing. Run 9 5/8' surface casing, circulating bottoms up every 1,000'. Land casing at 3,186' MD and rig up cementers. Pressure testing lines at time of report. Gas: There maximum trip gas was 13 units seen at 3110’ MD. Fluids: 0 barrels of water-based mud lost down hole. 09/26/2014 Begin pumping cement with 230 barrels lead cement and 50 barrels tail cement. Did not bump plug, but floats held. Dumped 78.5 barrels cement into cellar. Rig down cementers and diverter. Nippled up BOP and prepare for testing. Removing spud mud and cleaning pits at time of report. Gas: There was no gas seen during cement job. Fluids: 0 barrels of water-based mud lost down hole. 09/27/2014 Finished BOP test and mixing KCL mud. Pick up BHA, lay down extra heavy weight drill pipe and trip in hole on singles. Preparing to slip and cut drill line at time of report. Gas: There was no gas seen during BOP tests or tripping in the hole. Fluids: 0 barrels of water-based mud lost down hole. 09/28/2014 Drilled cement and 20' rat hole. Conducted formation integrity test to 11.8 ppg estimated mud weight. Drilled ahead TO 3,330’ MD and stopped for MWD tool failure. Circulate bottoms up, pump dry job, tripped out of hole for MWD. Lay down BHA and pick up new BHA. Run in hole on singles and begin to drill ahead at time of report. Gas: The maximum formation gas seen was 313 units at 3,289’ MD, the maximum connection gas was 136 units seen at 3,302’ MD, and there was no significant trip gas seen. Fluids: 0 barrels of water-based mud lost down hole. Geology: 100% Sandstone: light grey-grey, pal yellow, brown, green, translucent, opaque, very fine grain, loose, unconsolidated, trace Siltstone, trace Coal, trace Glauconite. 09/29/2014 Drill ahead from 3,331' MD to 3,955' MD. Pump sweep, drill ahead to 4,830' MD. Pump sweep, trip out of hole to shoe for wiper trip. Trip in hole on singles, back to bottom at time of report. Drilling ahead. Gas: The maximum formation gas seen was 112 units at 3,875’ MD, the maximum connection gas seen was 102 units at 3,720’ MD, and there was no significant trip gas seen. Fluids: 0 barrels of water-based mud lost down hole. Geology: 80% Siltstone: light grey, firm, poorly indurated, blocky, tuffaceous, slightly clayey, trace Tuff; 20% Sand: Light grey, brown, white, transparent-translucent, fine grain, sub round, well sorted, calcareous, silty. 09/30/2014 Ran in hole to 4,830' MD, drill ahead to 6,321' MD. Pump sweep, conducting short trip at time of report. Gas: The maximum formation gas seen was 1,000 units at 5,605’ MD, the maximum connection gas seen was 290 units at 5,753’ MD, and there was no significant trip gas seen. Fluids: 0 barrels of water-based mud lost down hole. Geology: 100% Sandstone: light grey, soft, very fine to coarse grain, occasional very coarse Quartz grains, sub round, poorly sorted, poor consolidation, silty matrix, tuffaceous, trace Coal, trace Siltstone. 10/01/2014 Completed wiper trip to 4,800' MD. Drilled ahead to 7,138' MD and pumped sweep. Drilled ahead, 7,260' MD at time of report. Gas: The maximum formation gas seen was 1343 units at 6,606’ MD, the maximum connection gas seen was 274 units at 6,587’ MD, and there was no significant trip gas. Fluids: 0 barrels of water-based mud lost down hole. Geology: 40% Siltstone: light grey, soft, massive, amorphous, poorly indurated, sandy, tuffaceous, abundant Quartz flakes; 30% Sandstone: Grey, soft, fine to course gain, sub round, poorly sorted, poorly consolidated, silty matrix, common large Quartz flakes, tuffaceous; 30% Shale: medium brown, soft, poorly indurated, flaky, earthy. 10/02/2014 Drilled ahead to 7,506' MD, pumped sweep. Wiper trip to 6,198' MD with over pull at 6,440' MD and 6,410' MD. Back reamed at both depths. Ran back to bottom on singles, drilling ahead, 7,965' MD at time of report. Gas: The maximum formation gas seen was 525 units at 7,930’ MD, the maximum connection gas seen was 152 units at 7,831’ MD, and there was a maximum of 46 units of trip gas. Fluids: 0 barrels of water-based mud lost down hole. Geology: 60% Claystone: grey, firm, tacky, pliable, silty, hydroturgid; 30% Siltstone: medium grey, soft, amorphous, poorly indurated, tuffaceous; 10% Coal: dark brown, soft-firm, moderately indurated, flaky, earthy. 10/03/2014 Drilled ahead to 8,502' MD, pumped sweep. Tripped out of hole, pumping at 6,184' MD. Pumped and reamed to 5,555' MD, back reaming out at time of report. Gas: The maximum formation gas seen was 714 units at 8365’ MD, the maximum connection gas seen was 125 units at 8086’ MD, and there was no significant trip gas. Fluids: 0 barrels of water-based mud lost down hole. Geology: 60% Siltstone : medium grey, occasional brown, soft occasional firm, amorphous, poorly indurated, tuffaceous, sandy; 40% Claystone : med grey, soft, tacky, poorly indurated, pliable, silty, non-swelling, SHOW: no visible fluorescence, bright yellow- bright green crush cut, bright yellow residual ring. 10/04/2014 Back reamed to 5,086' MD, finished tripping out of hole on elevators to shoe. Slipped and cut drill line, serviced rig, ran in hole on singles to 4,525' MD. Ran in hole on stands to 4,632' MD, washed and reamed to 5,301' MD, finished tripping in hole on elevators. Ran in hole to 8,429’ MD and tagged fill, washed to bottom. Drilling ahead at time of report. Gas: The maximum formation gas seen was 686 units at 8,672’ MD, the maximum connection gas seen was 417 units at 8,694’ MD, and there was a maximum of 65 units of trip gas. Fluids: 66 barrels of water-based mud lost down hole. Geology: 80% Siltstone : light brown, light grey-medium grey, soft-firm, amorphous-blocky, moderately indurated, tuffaceous; SHOW: no visible fluorescence, slow streaming blue white cut, 30% dull yellow crush cut, no residual ring. 20% Claystone: medium grey, firm, tacky, moderately indurated, pliable, non-swelling; 10% Coal: dark brown, soft-firm, mod indurated, flaky, earthy. 10/05/2014 Healed the hole and continued drilling ahead to 9,445' MD. Short tripped from 9,478' MD to 9,066' MD on elevators, having to screw in and pump through tight spots. Back reamed from 8,945' MD to 8,870' MD. Back reaming out for short wiper trip at time of report. Gas: The maximum formation gas seen was 4,142 units at 9,338’ MD, the maximum connection gas seen was 5,127 units at 9,371’ MD, and 76 units of trip gas was seen. Fluids: 75 barrels of water-based mud lost down hole. Geology: 90% Coal: black, hard, splintery, vitreous; SHOW: no stain, no visible fluorescence, slow streaming bright blue white cut, moderate dull white fluorescent residual ring, thin straw natural light residual ring; 10% Siltstone : light brown, light grey, firm with occasional hard, blocky, friable, tuffaceous, sandy. 10/06/2014 Complete wiper trip and run in hole to 9,476' MD. Encountered 24' of fill and pumped sweep. Drill ahead from 9,900' MD to 10,066' MD. Saw 60 percent flow increase and 5,592 units formation gas produced and 4,250 units connection gas. Circulated and monitored while weighting up mud to 10.1 ppg. Drill ahead from 10,066' MD to 10,127' MD; drilling ahead at time of report. Gas: The maximum formation gas seen was 5,597 units at 10,039’ MD, the maximum connection gas seen was 7,858 units at 9,556’ MD, and no tripping took place. Fluids: 0 barrels of water-based mud lost down hole. Geology: 30% Sandstone: light grey-tan, firm, fine-coarse grain, sub round, moderate-poor sorting, poorly consolidated, tuffaceous matrix; SHOW : no stain, no visible fluorescence, slow streaming bright white cut, no natural light residual ring; 30% Siltstone: tan-grey, f irm, blocky, friable; 20%Sand: translucent-transparent, fine-coarse grains, moderate sorting, sub round; 10% Tuff: white, soft, amorphous, sand; 10% Coal: black, soft-firm, mod indurated, splintery, brittle, earthy-vitreous. 10/07/2014 Drill ahead from 10,120' MD to 10,548' MD, pump sweep. Short trip from 10,548' MD to 9,400' MD. Tight spots occurred between 10,117' MD to 9,980' MD and 9,790' MD to 9,400' MD. Run in hole washing out 48' of fill. Circulate bottoms up 989 units of gas. Currently at 10,566' MD and drilling ahead at time of report. Gas: The maximum formation gas seen was 699 units at 10,442’ MD, the maximum connection gas seen was 606 units at 10,487’ MD, the maximum trip gas seen was 80 units going in the hole, and we saw a bottoms up of 998 units at 10,548’ MD. Fluids: 75 barrels of water-based mud lost down hole. Geology: 40% Sandstone : light grey, soft, fine-coarse grain, sub round, moderate-poorly sorted, poorly consolidated, tuff matrix; SHOW: no stain, no visible fluorescence, slow streaming dull white cut, no residual ring; 30% Siltstone : tan-brownish grey, firm, blocky, friable, tuffaceous, sandy; 20% Coal : black, firm-hard, blocky, flaky, angular, vitreous; 10% Sand : translucent-transparent, fine-coarse grain, poorly sorted, sub round. 10/08/2014 Drilling ahead from 10,566' MD to 11,170' MD, drilling ahead at time of report. Gas: The maximum formation gas seen was 1,408 units at 10,723’ MD, the maximum connection gas seen was 102 units at 10,735’ MD, and no tripping took place. Fluids: 0 barrels of water-based mud lost down hole. Geology: 80% Sandstone : light grey, soft, fine-coarse grain, sub round, moderate-well sorting, poor consolidation, tuffaceous matrix; SHOW: no stain, no visible fluorescence, moderate streaming bright white cut, no residual ring; 10% Siltstone : tan-brownish grey, firm, blocky, friable, tuffaceous, sandy, slightly indurated; 10% Coal: black, firm-hard, blocky, flaky, angular, vitreous. 10/09/2014 Drill ahead from 11,170' MD to 11,233' MD and pump sweep. Drill ahead to 11,300' MD and pump sweep. Call it TD. Wiper trip to 10,491' MD, back reaming two stands on trip. Ran back to bottom, pump sweep, circulate bottoms up. Back reaming out of hole at time of report. Gas: The maximum formation gas seen was 151 units at 11,282’ MD, the maximum connection gas seen was 135 units at 11,287’ MD, and a maximum trip gas of 498 units was seen at 11,290’ MD. Fluids: 0 barrels of water-based mud lost down hole. Geology: 50% Siltstone: grey- brownish grey, firm, blocky, friable, sandy, moderately indurated; SHOW: no stain, no visible fluorescence, slow streaming blue white cut, no residual ring; 20% Sandstone: white-light grey, soft, fine-coarse grain, sub round, moderately sorted, poorly consolidated, tuffaceous matrix; 20% Shale: light grey, light brown, firm, blocky, flaky, indurated; 10% Coal: black, firm-hard, blocky, flaky, angular, vitreous. 10/10/2014 Back reamed to 6,615' MD and began pulling on elevators. Tripped out of hole to surface. Lay down BHA, rig up to test BOP at time of report. Gas: Maximum trip gas seen was 21 units. Fluids: 0 barrels of water-based mud lost down hole. 10/11/2014 Completed testing of BOP, pick up clean out assembly, run in hole to shoe, serviced rig, run in hole to 8,778' MD. Circulate bottoms up 8,943U. Run in hole with tight spots at 8,824' MD, 9,867' MD, and 10,070' MD. Run in hole, 9,915' MD at time of report. Gas: Maximum trip gas seen was 8943 units. Fluids: 0 barrels of water-based mud lost down hole. 10/12/2014 Ran in hole to 10,132’ MD, circulated bottoms up 9,648 units of gas and continued to circulate. 15 percent increase in flow, shut in well. Weighted up mud to 10.3 ppg and circulated through choke. Well stabilized and ran to bottom, weighted up mud to 10.4 ppg. Pumped sweep and began pulling out of hole. Pulling out of hole at time of report. Mas Gas: Maximum trip gas 9,648 units. Fluids: 0 barrels of water-based mud lost down hole. 10/13/2014 Finish laying down drill pipe and clean out assembly. Change rams and test with bag. Rig up Weatherford and run in hole with 5.5" casing. Circulate bottoms up at 3,156' MD with 63 units of gas. Running in hole at 4,581' MD at time of report. Mas Gas: Maximum trip gas 63 units. Fluids: 0 barrels of water-based mud lost down hole. 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 0 5 10 15 20 25 Me a s u r e d D e p t h Rig Days WELL NAME: BCU 24 OPERATOR: Hilcorp MUD CO: Baroid RIG: Saxon 169 SPERRY JOB: SDL Days vs. Depth 21 September 2014 Sperry SDL Arrived on Location LOCATION: Kenai AREA: Beaver Creek STATE: Alaska SPUD: 22 September 2014 TD: WELL NAME: BCU 24 OPERATOR: Hilcorp MUD CO: Baroid RIG: Saxon 169 SPERRY JOB: SDL Days vs. Depth 21 September 2014 Sperry SDL Arrived on Location LOCATION: Kenai AREA: Beaver Creek STATE: Alaska SPUD: 22 September 2014 TD: WELL NAME: BCU 24 OPERATOR: Hilcorp MUD CO: Baroid RIG: Saxon 169 SPERRY JOB: SDL Days vs. Depth 21 September 2014 Sperry SDL Arrived on Location LOCATION: Kenai AREA: Beaver Creek STATE: Alaska SPUD: 22 September 2014 TD: WELL NAME: BCU 24 OPERATOR: Hilcorp MUD CO: Baroid RIG: Saxon 169 SPERRY JOB: SDL Days vs. Depth 21 September 2014 Sperry SDL Arrived on Location LOCATION: Kenai AREA: Beaver Creek STATE: Alaska SPUD: 22 September 2014 TD: WELL NAME: BCU 24 OPERATOR: Hilcorp MUD CO: Baroid RIG: Saxon 169 SPERRY JOB: SDL Days vs. Depth 21 September 2014 Sperry SDL Arrived on Location LOCATION: Kenai AREA: Beaver Creek STATE: Alaska SPUD: 22 September 2014 TD: WELL NAME: BCU 24 OPERATOR: Hilcorp MUD CO: Baroid RIG: Saxon 169 SPERRY JOB: SDL Days vs. Depth 21 September 2014 Sperry SDL Arrived on Location LOCATION: Kenai AREA: Beaver Creek STATE: Alaska SPUD: 22 September 2014 TD: WELL NAME: Beaver Creek Unit 24 OPERATOR: Hilcorp Alaska, LLC MUD CO: Baroid RIG: Saxon 169 SPERRY JOB: AK-AM-0901663907 Days vs. Depth 21 Sep 2014 Sperry SDL Arrived on Location LOCATION: Beaver Creek AREA: Kenai Peninsula Borough STATE: Alaska SPUD: 22-Sep-2014 TD: 9-Oct-2014 Commenced 12.25" Surface Hole Section On Bot: 16:20 22 Sep 2014 TD Surface Hole Section 3200' MD, 2945' TVD Off Bot: 16:55 24 Sep 2014 Commenced 8.5" Production Hole Section On Bot: 06:29 28 Sep 2014 Landed 9.625" Surface Casing 3186' MD, 2932' TVD 25 Sep 2014 POOH for MWD Tool Failure 28 Sep 2014 Drill 8.5" hole to 4830' MD STP to clean hole 29 Sep 2014 Drill 8.5" hole to 4800' MD STP to clean hole 1 Oct 2014 Drill 8.5" hole to 6320' MD STP to clean hole 30 Sep 2014 Drill 8.5" hole to 6198' MD STP to clean hole 2 Oct 2014 Drill 8.5" hole to 8502' MD STP to shoe to clean hole 3 Oct 2014 Drill 8.5" hole to 10548' MD STP to clean hole 7 Oct 2014 Drill 8.5" hole to 9445' MD STP to clean hole 5 Oct 2014 TD Production Hole Section 11300' MD, 10698' TVD Off Bot: 05:33 9 Oct 2014 WELL NAME:LOCATION: OPERATOR:AREA:Kenai Peninsula Borough SPERRY JOB:STATE: RIG:Saxon 169 HOLE SECTION:Surface EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 AK-XX-0091663907 Alaska Beaver Creek Unit 24 Beaver Creek Hilcorp Alaska, LLC Jane Grundin 28-Sep-2014 What went as, or better than, planned: Gas equipment functioned properly, WITS and PASON functioned without error. Using data exchange with MWD for real-time data transfer instead of LAS file imports provided up-to-date real time data. Difficulties experienced: N/A Recommendations: N/A Innovations and/or cost savings: Hooked up gas trap and air tank to rig air, allowing us independence from the air compressor. Will save money on shipping as well as saving some hassel or possible down time from air compressor failures. Surface Data Logging After Action Review WELL NAME:LOCATION: OPERATOR:AREA:Kenai Peninsula Borough SPERRY JOB:STATE: RIG:Saxon 169 HOLE SECTION:Production Hole EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Jacob Hansen/Jane Grundin 22-Oct-2014 What went as, or better than, planned: We started putting caught samples in the long black plastic trays so that we could look back at old samples that had been processed. This was very helpful for us because we were able to show the company men what we had been drilling through as well as looking back at a particular samples of interest. Difficulties experienced: Problems involving the chromatograph required us to switch to the backup. However that was not calibrating to it's full potential and data was lost. Recommendations: Pay closer attention to gas equipment calibrations, especially when the connection is broken between the chromatograph and Insite. Always double check numbers and recalibrate whenever possible. Innovations and/or cost savings: N/A AK-XX-0091663907 Alaska Beaver Creek Unit 24 Beaver Creek Hilcorp Alaska, LLC Surface Data Logging After Action Review WELL NAME:Beaver Creek Unit 24 LOCATION:Beaver Creek OPERATOR:Hilcorp Alaska, LLC AREA:Kenai Peninsula Borough MUD CO:Baroid STATE:Alaska RIG:Saxon 169 SPUD:22-Sep-2014 SPERRY JOB:AK-AM-0901663907 TD:9-Oct-2014 Marker MD INC AZ TVD TVDSS SHALLOW_GAS1 3,246.0 28.6 135.5 2,985.0 -2,807.0 STERLING_B 5,338.0 27.7 130.4 4,842.0 -4,664.0 BC_B1ST 5,375.0 27.7 130.4 4,875.0 -4,697.0 BC_B1-L_ST 5,436.0 27.7 130.7 4,929.0 -4,751.0 BC_B2ST 5,502.0 27.5 131.2 4,987.0 -4,809.0 BC_B-2_PAY 5,600.0 27.3 130.8 5,074.0 -4,896.0 BC_B-3_PAY 5,644.0 27.3 130.5 5,113.0 -4,935.0 BC_B3ST 5,640.0 27.3 130.5 5,110.0 -4,932.0 BC_B3-L_ST 5,716.0 27.3 131.3 5,177.0 -4,999.0 BC_B-3_LWR_PAY 5,723.0 27.3 131.3 5,184.0 -5,006.0 BC_B-4_PAY 5,846.0 25.6 132.8 5,294.0 -5,116.0 BC_B4ST 5,847.0 25.6 132.8 5,294.0 -5,116.0 BELUGA 6,474.0 14.3 133.3 5,882.0 -5,704.0 U_BELUGA 6,506.0 12.4 134.3 5,913.0 -5,735.0 UBC1 6,574.0 11.1 134.9 5,980.0 -5,802.0 BCU BELUGA PAY 6,593.0 11.1 134.9 5,998.0 -5,820.0 UBC3 6,723.0 8.9 134.0 6,126.0 -5,948.0 M_BELUGA 7,058.0 5.8 134.2 6,459.0 -6,281.0 BC_B15ST 7,454.0 4.4 135.1 6,854.0 -6,676.0 BC_B16ST 7,761.0 4.6 132.0 7,160.0 -6,982.0 SR_LBGT 7,824.0 4.5 132.8 7,223.0 -7,045.0 BC_B18UST 7,887.0 5.0 132.0 7,285.0 -7,107.0 BC_B19ST 7,984.0 4.9 129.8 7,382.0 -7,204.0 BC_B20ST 8,028.0 4.8 131.3 7,426.0 -7,248.0 BCU BELUGA PAY 8,034.0 4.8 131.3 7,432.0 -7,254.0 LWR_BELUGA 8,113.0 4.8 131.0 7,510.0 -7,332.0 BC_B22ST 8,225.0 4.0 131.2 7,622.0 -7,444.0 BCU BELUGA PAY 8,263.0 2.9 131.7 7,660.0 -7,482.0 BCU BELUGA PAY 8,276.0 2.9 131.7 7,673.0 -7,495.0 BC_B23ST 8,302.0 2.9 131.7 7,699.0 -7,521.0 BCU BELUGA PAY 8,325.0 1.5 143.1 7,722.0 -7,544.0 BC_B24X_ST 8,326.0 1.5 143.1 7,723.0 -7,545.0 BC_B24ST 8,385.0 0.3 199.4 7,782.0 -7,604.0 BCU BELUGA PAY 8,390.0 0.3 199.4 7,787.0 -7,609.0 BC_B26ST 8,450.0 0.3 239.4 7,847.0 -7,669.0 BC_B27ST 8,488.0 0.3 239.4 7,885.0 -7,707.0 BCU BELUGA PAY 8,541.0 0.3 243.2 7,938.0 -7,760.0 BC_B28ST 8,557.0 0.3 246.9 7,954.0 -7,776.0 BCU BELUGA PAY 8,566.0 0.3 246.9 7,963.0 -7,785.0 BC_B28SB 8,707.0 0.4 242.1 8,104.0 -7,926.0 BC_B30ST 8,825.0 0.6 273.6 8,222.0 -8,044.0 BCU BELUGA PAY 8,834.0 0.6 273.6 8,231.0 -8,053.0 BCU BELUGA PAY 8,845.0 0.6 273.6 8,242.0 -8,064.0 BC_B31ST 8,920.0 0.3 245.5 8,317.0 -8,139.0 BC_B31_C_ST 9,012.0 0.4 245.6 8,409.0 -8,231.0 BC_B32SB 9,162.0 0.5 244.3 8,559.0 -8,381.0 SR_TYONEK 9,313.0 0.7 283.8 8,710.0 -8,532.0 TYONEK GAS 9,328.0 0.7 283.8 8,725.0 -8,547.0 BC_T-1_15CT 9,699.0 0.7 319.6 9,096.0 -8,918.0 TYONEK GAS 10,016.0 0.6 285.8 9,413.0 -9,235.0 SR_D1CT 10,409.0 0.6 279.6 9,806.0 -9,628.0 BC_T10ST 10,452.0 0.6 270.5 9,849.0 -9,671.0 BC_T10SD 10,453.0 0.6 270.5 9,850.0 -9,672.0 Formation Tops WELL NAME:Beaver Creek Unit 24 LOCATION:Beaver Creek OPERATOR:Hilcorp Alaska, LLC AREA:Kenai Peninsula Borough MUD CO:Baroid STATE:Alaska RIG:Saxon 169 SPUD:22-Sep-2014 SPERRY JOB:AK-AM-0901663907 TD:9-Oct-2014 Marker MD INC AZ TVD TVDSS BC_T10SB 10,471.0 0.6 270.5 9,868.0 -9,690.0 BC_T12ST 10,666.0 0.6 263.0 10,063.0 -9,885.0 BC_T17ST 10,778.0 0.6 271.0 10,175.0 -9,997.0 BC_T18ST 10,849.0 0.8 277.0 10,246.0 -10,068.0 BC_T19ST 10,980.0 0.7 289.2 10,377.0 -10,199.0 BC_T19SD 10,985.0 0.7 289.2 10,382.0 -10,204.0 BC_T19SD 11,007.0 0.7 289.2 10,404.0 -10,226.0 BC_T19SB 11,068.0 0.7 294.1 10,465.0 -10,287.0 BC_T20ST 11,127.0 0.8 285.6 10,524.0 -10,346.0 TYONKEY GAS 11,129.0 0.8 285.6 10,526.0 -10,348.0 TYONEK GAS 11,160.0 0.8 286.2 10,557.0 -10,379.0 BC_T20SB 11,195.0 0.8 286.2 10,592.0 -10,414.0 Formation Tops Well Name:Depth (MD)to ft Location:(TVD)to ft Operator: Report Prepared By:Formation: Report Delivered To:Date: No Depth ft C1 C1 C1 C1. Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1. Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 0 0 0 0.00 0 0 0 - 0 0 0 - 29500 28286 8239 20047 2005 16 6 10 - 4 5851 Gas Units 212 Mud Chlorides (mg/L) = 0 0 0 - 0 0 0 43 6 37 - 0 0 0 - 5728 Gas Units 442 Mud Chlorides (mg/L) =29500 56627 8239 48388 1308 0 0 0 3 Hydrocarbon Ratios 0 0 0 - 0 0 0 - 29500 60419 8239 52180 1373 44 6 38 - 0 0 0 2 5657 Gas Units 478 Mud Chlorides (mg/L) = 0 0 0 - 86 6 80 - 0 0 0 - 118629 8239 110390 1380 1 Hydrocarbon Ratios 5606 Gas Units 1000 Mud Chlorides (mg/L) =29500 Brt Yel Oil Show Rating Free Oil in Mud abnd Color Brt Yel Color Cut Color N/A Intensity straw Color N/A Intensity N/A Color Brt Yel Residual Flourescence abnd Amount N/A Distribution N/A Intensity Abnd Color Stain Amount N/A Type Crsh Ct Amount Cuttings Analysis: Odor Fnt Fluorescence Cut Fluorescence Residual Cut Grundin/Hansen STERLING_B John Serbeck 10/11/2014 Interpretation: Show intervals show good charateristics in lithoilogy and resistivity for potential pay zones. However gas data indicates that heavy gases associated with show intervals were not abundant to non existent. Potential oil fluorescence was found in one show interval while using IPA as a cutting agent. Oil cut was found only when crushed. Fluorescence showed a bright yellow cut with a bright yellow residual ring. Under natural light the residual ring was seen as a straw color to a light brown. Odor was faint to non existent in all show intevals. Show Report Report # 1 Beaver Creek Unit 24 5600 5856 Beaver Creek 5074 5303 Hilcorp Alaska, LLC Oil Gas NPH NPH NPH Oil Gas NPH 1 10 100 1000 Oil Gas NPH NPH 1 10 100 1000 NPH Oil Gas NPH Well Name:Depth (MD)to ft Location:(TVD)to ft Operator: Report Prepared By:Formation: Report Delivered To:Date: Yes Depth ft C1 C1 C1 C1. Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 0 0 0 11 0 11 9756 4 0 4 - 32000 46954 7932 39022 1774 30 8 22 3547 0 0 0 2 8042 Gas Units 233 Mud Chlorides (mg/L) = 0 0 0 - 105 13 92 15406 9 0 9 - 152654 14003 138651 1507 1 Hydrocarbon Ratios 6606 Gas Units 1343 Mud Chlorides (mg/L) =29500 Bl-Wt Oil Show Rating Free Oil in Mud Abnd Color Bl-Wt Color Cut Color N/A Intensity Strw-Lt Brn Color N/A Intensity N/A Color Bl-Wt Residual Flourescence Abnd Amount N/A Distribution N/A Intensity Abnd Color Stain Amount N/A Type Strmg Amount Cuttings Analysis: Odor Fnt Fluorescence Cut Fluorescence Residual Cut Grundin/Hansen BELUGA John Serbeck 10/10/2014 Interpretation: Show intervals show a good potential for hydrocarbons due to the increase in gas and resistivity in the zones of interest. Gas data indicates that heavy gases are present in these areas. Lithology is a quartz rich, partially consolidated sandstone with an increase in siltstones and claystones interbedded. There was free oil residue found in cuttings box. Fluorescents were found inside show intervals, but only when IPA was used as a cutting agent. This showed a moderate streaming cut with no crush. Show Report Report # 2 Beaver Creek Unit 24 6593 8057 Beaver Creek 5998 7455 Hilcorp Alaska, LLC Oil Gas NPH NPH 1 10 100 1000 Oil Gas NPH NPH Well Name:Depth (MD)to ft Location:(TVD)to ft Operator: Report Prepared By:Formation: Report Delivered To:Date: Yes Depth ft C1 C1 C1 C1. Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1. Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 0 0 0 0.00 13 2 11 4375 6 0 6 - 33000 37178 10926 26252 1141 31 8 23 2387 4 8407 Gas Units 180 Mud Chlorides (mg/L) = 0 0 0 16928 2 0 2 34 8 26 2821 14 2 12 - 8337 Gas Units 225 Mud Chlorides (mg/L) =33000 44781 10926 33855 1302 0 0 0 3 Hydrocarbon Ratios 6 2 4 - 0 0 0 - 33000 25324 10926 14398 1440 18 8 10 3600 0 0 0 2 8278 Gas Units 121 Mud Chlorides (mg/L) = 0 0 0 - 19 8 11 3197 9 2 7 - 33303 10926 22377 2034 1 Hydrocarbon Ratios 8268 Gas Units 163 Mud Chlorides (mg/L) =32000 bl-wt Oil Show Rating Free Oil in Mud abnd Color N/A Color Cut Color N/A Intensity strw-lt brn Color N/A Intensity N/A Color bl-wt Residual Flourescence abnd Amount N/A Distribution N/A Intensity abnd Color Stain Amount N/A Type stmg Amount Cuttings Analysis: Odor Fnt Fluorescence Cut Fluorescence Residual Cut Grundin/Hansen LWR_BELUGA John Serbeck 10/11/2014 Interpretation: Show intervals show a good potential for hydrocarbons due to the increase in gas and resistivity in the zones of interest. Gas data indicates that only some of show intervals showed that heavy gases were present in the areas of interest. Lithology indicates that the show intervals were mostly claystones and siltstones with some occasional shales and sands interbedded. Free oil residue was found in cuttings box. Fluorescents were found inside show intervals, but only when IPA was used as a cutting agent. This showed a moderate streaming cut with no crush. Show Report Report # 3 Beaver Creek Unit 24 8263 8414 Beaver Creek 7660 7811 Hilcorp Alaska, LLC Oil Gas NPH NPH NPH Oil Gas NPH 1 10 100 1000 Oil Gas NPH NPH 1 10 100 1000 NPH Oil Gas NPH Well Name:Depth (MD)to ft Location:(TVD)to ft Operator: Report Prepared By:Formation: Report Delivered To:Date: Yes Depth ft C1 C1 C1 C1. Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1. Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 =C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 0 0 0 0.00 6 0 6 - 0 0 0 - 33500 17016 4358 12658 1055 12 0 12 2110 4 8853 Gas Units 75 Mud Chlorides (mg/L) = 0 0 0 - 0 0 0 12 0 12 2424 6 0 6 - 8841 Gas Units 84 Mud Chlorides (mg/L) =33500 18904 4358 14546 1212 1 0 1 3 Hydrocarbon Ratios 10 0 10 - 0 0 0 23194 33500 27552 4358 23194 1289 18 0 18 2319 1 0 1 2 8578 Gas Units 140 Mud Chlorides (mg/L) = 15 0 15 62421 40 0 40 3285 19 0 19 4161 66779 4358 62421 1561 1 Hydrocarbon Ratios 8560 Gas Units 344 Mud Chlorides (mg/L) =33500 bl-wt Oil Show Rating Free Oil in Mud abnd Color N/A Color Cut Color N/A Intensity strw-lt brn Color N/A Intensity N/A Color bl-wt Residual Flourescence abnd Amount N/A Distribution N/A Intensity abnd Color Stain Amount N/A Type Mod stmg Amount Cuttings Analysis: Odor Fnt Fluorescence Cut Fluorescence Residual Cut Grundin/Hansen LWR_BELUGA John Serbeck 10/11/2014 Interpretation: Show intervals show a good potential for hydrocarbons due to the increase in gas and resistivity in the zones of interest. Gas data indicates that only some of show intervals showed that heavy gases were present. Lithology indicates that the show intervals were mostly claystones and siltstones. Occasionally there were possible coal stringers and shales interbedded. Free oil residue found in cuttings box. Fluorescents were found inside show intervals, but only when IPA was used as a cutting agent. This showed a moderate streaming cut with no crush. Show Report Report # 4 Beaver Creek Unit 24 8541 8854 Beaver Creek 7938 7971 Hilcorp Alaska, LLC Oil Gas NPH NPH NPH Oil Gas NPH 1 10 100 1000 Oil Gas NPH NPH 1 10 100 1000 NPH Oil Gas NPH Well Name:Depth (MD)to ft Location:(TVD)to ft Operator: Report Prepared By:Formation: Report Delivered To:Date: Yes Depth ft C1 C1 C1 C1. Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 28 0 28 443 16 427 6498 109 0 109 25296 32500 745535 37241 708294 730 1011 41 970 1659 22 0 22 2 10035 Gas Units 5538 Mud Chlorides (mg/L) = 54 0 54 19955 436 15 421 1330 337 7 330 8130 452628 13620 439008 1043 1 Hydrocarbon Ratios 9338 Gas Units 4142 Mud Chlorides (mg/L) =3200 Wt Oil Show Rating Free Oil in Mud Abnd Color Wt Color Cut Color N/A Intensity Strw Color N/A Intensity N/A Color Wt Residual Flourescence Abnd Amount N/A Distribution N/A Intensity Abnd Color Stain Amount N/A Type Blm Amount Cuttings Analysis: Odor Fnt Fluorescence Cut Fluorescence Residual Cut Grundin/Hansen SR_TYONEK John Serbeck 10/11/2014 Interpretation: Show intervals show a good potential for hydrocarbons due to the increase in gas and resistivity in the zones of interest. Gas data indicates that heavy gases are present in these areas. Lithology is a quartz rich, partially consolidated sandstone with occasional high percentages of siltstones. Coal stringers and claystones are frequent between show intervals. Free oil residue was found in cuttings box. Fluorescents were found inside show intervals, but only when IPA was used as a cutting agent. This showed a moderate streaming cut with no crush. Show Report Report # 5 Beaver Creek Unit 24 9328 10042 Beaver Creek 8725 9439 Hilcorp Alaska, LLC Oil Gas NPH NPH 1 10 100 1000 Oil Gas NPH NPH Well Name:Depth (MD)to ft Location:(TVD)to ft Operator: Report Prepared By:Formation: Report Delivered To:Date: Yes Depth ft C1 C1 C1 C1. Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft C1 C1 C1 C1. Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water Non-Producible Hydrocarbons ---0.00 ---0 ---0 ---0 ---0 4 Gas Units Mud Chlorides (mg/L) = 19 33 -14 -129 1 0 1 34 31 3 -7 18 0 18 9 11028 Gas Units 25 Mud Chlorides (mg/L) =31500 605 734 -129 -43 0 0 0 3 Hydrocarbon Ratios 17 8 9 -550 19 0 19 - 31500 637 11096 -10459 -581 33 15 18 -1162 0 0 0 2 10993 Gas Units 25 Mud Chlorides (mg/L) = 0 0 0 - 82 15 67 1154 49 8 41 - 58420 11096 47324 706 1 Hydrocarbon Ratios 10470 Gas Units 261 Mud Chlorides (mg/L) =31500 Bl-Wt Oil Show Rating Free Oil in Mud Abnd Color Bl-Wt Color Cut Color N/A Intensity Brn Color N/A Intensity N/A Color Bl-Wt Residual Flourescence Abnd Amount N/A Distribution N/A Intensity Abnd Color Stain Amount N/A Type Mod Stmg Amount Cuttings Analysis: Odor Fnt Fluorescence Cut Fluorescence Residual Cut Grundin/Hansen SR_D1CT John Serbeck 10/11/2014 Interpretation: Show intervals show a good potential for hydrocarbons due to the increase in gas and resistivity in the zones of interest. Gas data indicates that heavy gases are present in these areas. Lithology is a quartz rich, partially consolidated sandstone with occasional high percentages of siltstones. Coal stringers are frequent between show intervals. Free oil residue was found in cuttings box. Fluorescents were found inside show intervals, but only when IPA was used as a cutting agent. This showed a moderate streaming cut with no crush. Show Report Report # 6 Beaver Creek Unit 24 10453 11047 Beaver Creek 9850 10444 Hilcorp Alaska, LLC Oil Gas NPH NPH NPH Oil Gas NPH 1 10 100 1000 Oil Gas NPH NPH 1 10 100 1000 NPH Oil Gas NPH Well Name:Depth (MD)to ft Location:(TVD)to ft Operator: Report Prepared By:Formation: Report Delivered To:Date: Yes Depth ft C1 C1 C1 C1. Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons Depth ft . Flowline Background Show ppm ppm ppm Hydrocarbon Ratios C1 -=C1/C2 = C2 -=C1/C3 = C3 -=C1/C4 = C4 -=C1/C5 = C5 -= Production Analysis Gas Oil Water x Non-Producible Hydrocarbons 0 0 0 15 9 6 - 18 18 0 - 33000 509 358 151 19 29 21 8 25 0 0 0 2 11176 Gas Units 19 Mud Chlorides (mg/L) = 16 18 -2 - 28 21 7 26 15 9 6 -78 513 358 155 22 1 Hydrocarbon Ratios 11131 Gas Units 20 Mud Chlorides (mg/L) =33000 N/A Oil Show Rating Free Oil in Mud N/A Color Bl-Wt Color Cut Color N/A Intensity N/A Color N/A Intensity N/A Color Bl-Wt Residual Flourescence N/A Amount N/A Distribution N/A Intensity Abnd Color Stain Amount N/A Type Mod Stmg Amount Cuttings Analysis: Odor Fnt Fluorescence Cut Fluorescence Residual Cut Grundin/Hansen SR-D1CT John Serbeck 10/11/2014 Interpretation: Show intervals show good charateristics in lithoilogy and resistivity for potential pay zones. Gas data indicates that heavy gases are present in these areas. Lithology is a quartz rich, partially consolidated sandstone with occasional high percentages of siltstones. Coal stringers are frequent between show intervals. Free oil residue was found in cuttings box. Fluorescents were found inside show intervals, but only when IPA was used as a cutting agent. This showed a moderate streaming cut with no crush. Show Report Report # 7 Beaver Creek Unit 24 11129 11195 Beaver Creek 10526 10592 Hilcorp Alaska, LLC Oil Gas NPH NPH 1 10 100 1000 Oil Gas NPH NPH WELL NAME:Beaver Creek Unit 24 LOCATION:Beaver Creek OPERATOR:Hilcorp Alaska, LLC AREA:Kenai Peninsula Borough MUD CO:Baroid STATE:Alaska RIG:Saxon 169 SPUD:22-Sep-2014 SPERRY JOB:AK-AM-0901663907 TD:9-Oct-2014 API:50-133-20639-00-00 AFE:1412278D BOX/SAMPLE (DRY)TOP DEPTH BOTTOM DEPTH SAMPLE COUNT WELL Box 1 of 10 3200 3980 39 BCU 24 Box 2 of 10 3980 4820 42 BCU 24 Box 3 of 10 4820 5780 48 BCU 24 Box 4 of 10 5780 6660 44 BCU 24 Box 5 of 10 6600 7540 47 BCU 24 Box 6 of 10 7540 8280 37 BCU 24 Box 7 of 10 8280 9020 37 BCU 24 Box 8 of 10 9020 9860 42 BCU 24 Box 9 of 10 9860 10840 49 BCU 24 Box 10 of 10 10840 11300 23 BCU 24 BOX/SAMPLE (DRY)TOP DEPTH BOTTOM DEPTH SAMPLE COUNT WELL Box 1 of 10 3200 3980 39 BCU 24 Box 2 of 10 3980 4820 42 BCU 24 Box 3 of 10 4820 5780 48 BCU 24 Box 4 of 10 5780 6660 44 BCU 24 Box 5 of 10 6600 7540 47 BCU 24 Box 6 of 10 7540 8280 37 BCU 24 Box 7 of 10 8280 9020 37 BCU 24 Box 8 of 10 9020 9860 42 BCU 24 Box 9 of 10 9860 10840 49 BCU 24 Box 10 of 10 10840 11300 23 BCU 24 BOX/SAMPLE (DRY)TOP DEPTH BOTTOM DEPTH SAMPLE COUNT WELL Box 1 of 10 3200 3880 34 BCU 24 Box 2 of 10 3880 4800 46 BCU 24 Box 3 of 10 4800 5760 48 BCU 24 Box 4 of 10 5760 6680 46 BCU 24 Box 5 of 10 6680 7540 43 BCU 24 Box 6 of 10 7540 8280 37 BCU 24 Box 7 of 10 8280 9020 37 BCU 24 Box 8 of 10 9020 9860 42 BCU 24 Box 9 of 10 9860 10840 49 BCU 24 Box 10 of 10 10840 11300 23 BCU 24 Sample Transmittal SAMPLE TRANSMITTAL DETAILS - Set 3 COMMENTS SAMPLE TRANSMITTAL DETAILS - Set 1 COMMENTS SAMPLE TRANSMITTAL DETAILS - Set 2 COMMENTS Beaver Creek Unit 24 Hilcorp Alaska, LLC Baroid Saxon 169 AK-AM-0901663907 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++ 21-Sep -8.80 190 29 53 45/66/84 11.0 111/82/69/54/33/32 -3.4 0.0/96.3 -0.35 8.8 -0.10/0.70 800 20 Rigging up, mixing spud mud 22-Sep 344 8.85 190 41 45 24/48/58 8.6 127/86/70/51/21/19 2/0 3.9 0.0/95.9 0.05 0.30 8.4 19.0 0.00/0.40 500 20 Drilling Surface Hole Section 23-Sep 1510 9.00 170 39 55 25/49/56 8.0 133/94/77/56/25/22 2/0 5.0 0.0/94.7 0.20 0.20 8.4 22.0 0.00/0.40 400 20 Drilling ahead 24-Sep 3200 9.40 66 22 24 11/35/47 7.6 68/46/38/27/11/10 2/0 8.0 0.0/91.8 0.50 0.10 7.7 18.8 0.00/0.40 500 10 TD Surface Hole Section 25-Sep 3200 9.50 56 17 14 5/12/16 7.6 48/31/24/16/5/4 1/0 8.3 0.0/91.5 0.50 -7.2 18.8 0.05/0.45 550 10 Landed Casing, R/U Cement 26-Sep 3200 9.60 44 9 16 5/8/12 6.3 34/25/21/16/6/4 1/2 6.9 0.0/91.7 0.10 0.10 8.1 5.5 0.05/3.00 27000 280 Testing BOP 27-Sep 3200 9.30 46 8 17 7/11/13 5.8 33/25/21/17/7/6 1/2 4.8 0.0/92.9 0.10 0.20 8.6 4.0 0.01/1.60 29000 150 RIH to Drill Production Section 28-Sep 3331 9.40 45 9 16 5/9/11 5.1 34/25/21/16/6/4 1/2 5.3 0.0/92.1 0.10 0.55 9.3 3.5 0.0/2.50 32000 440 Drill Ahead 8 1/2" Hole 29-Sep 4830 9.30 48 12 16 5/7/10 4.4 40/28/23/17/5/4 1/2 4.5 0.0/92.8 0.10 0.60 9.2 4.5 0.25/3.00 33500 300 TIH from Short Trip 30-Sep 6321 9.25 59 14 21 5/9/13 4.7 49/35/28/20/7/5 1/2 4.5 0.0/93.1 0.25 0.10 8.8 4.5 0.05/2.50 29500 420 Short Trip 1-Oct 7198 9.30 57 15 19 5/8/11 4.6 49/34/29/20/6/4 1/2 4.5 0.0/92.8 0.15 0.40 9.1 4.0 0.20/2.00 33000 240 Drill Ahead 8 1/2" Hole 2-Oct 7910 9.30 63 17 20 4/6/8 4.6 54/37/29/20/5/4 1/2 4.6 0.0/92.8 0.20 0.55 9.5 3.8 0.30/1.80 32000 100 Drill Ahead 8 1/2" Hole 3-Oct 8502 9.40 65 16 20 4/7/10 4.4 52/36/29/20/5/3 1/2 5.1 0.0/92.2 0.20 1.00 10.4 3.5 0.55/2.10 33000 20 Short Trip to Shoe 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 Remarks ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds %%%ppb Eqv mg/l Ca++ 4-Oct 8840 9.4 58 19 22 4/8/11 4.3 60/41/33/22/5/4 1/2 5.1 0.0/92.2 0.20 1.00 10.4 3.5 0.50/2.20 33500 40 Drill Ahead 8 1/2" Hole 5-Oct 9478 9.65 64 19 21 4/7/10 3.8 59/40/32/22/5/3 1/2 5.6 0.0/91.8 0.20 0.75 9.9 3.5 0.30/1.6 32000 60 Short Trip 6-Oct 10121 10.1 64 21 23 5/8/12 3.4 65/44/35/23/5/4 1/2 7.7 0.0/89.8 0.20 0.60 9.1 3.5 0.20/1.5 32500 40 Drill Ahead 8 1/2" Hole 7-Oct 10550 10.1 61 21 20 4/5/8 3.3 62/41/32/21/4/3 1/2 7.9 0.0/89.6 0.20 0.40 9.1 3.5 0.20/1.20 31500 60 Drill Ahead 8 1/2" Hole 8-Oct 11133 10.1 63 22 21 5/7/10 3.2 65/43/34/22/5/3 1/2 8.1 0.0/89.3 0.25 0.80 10.2 4.0 0.40/1.50 33000 40 Drill Ahead 8 1/2" Hole 9-Oct 11300 10.15 60 20 23 5/9/14 3.2 63/43/35/24/6/4 1/2 8.1 0.0/89.3 0.20 1.10 10.7 4.0 0.40/1.60 34000 40 TD Produciton Hole Section 10-Oct 11300 10.1 63 19 25 6/10/13 3.3 63/44/36/24/7/5 1/2 8.3 0.0/89.2 0.20 0.45 9.4 4.0 0.22/0.90 32500 40 R/U to test BOP 11-Oct 11300 10.15 55 15 23 7/12/17 3.4 53/38/31/23/7/5 1/2 8.7 0.0/88.9 0.25 0.15 8.4 3.5 0.10/0.80 31500 40 TIH/ Clean Out Run 12-Oct 11300 10.45 53 14 23 8/16/22 4.1 51/37/31/23/8/7 1/2 9.8 0.0/87.8 0.25 0.10 8.6 4.0 0.10/1.30 31000 40 POOH 13-Oct 11300 10.4 56 15 24 8/15/20 4.4 54/39/33/24/9/7 1/2 9.6 0.0/88.0 0.25 0.20 8.4 4.0 0.10/1.70 31500 60 Run 5.5" Casing Casing Record WELL NAME:LOCATION:Beaver Creek OPERATOR:AREA:Kenai Peninsula Borough MUD CO:STATE:Alaska RIG:SPUD:22-Sep-2014 SPERRY JOB:TD:9-Oct-2014 Remarks 16" Conductor @ 80' MD, 80' TVD 9.625" Casing @ 3186' MD, 2932' TVD 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 1 100 1 VM-3 12.25 72 3200 3128 25.47 0.942 122.8 27 85 2260 510 1-1-WT-AE-I-NO-TD TD Surface Section 2 200 2 PDC 8.50 3200 3330 130 1.02 0.663 224.0 5 50 1250 445 1-1-WT-A-X-I-NO POOH MWD Tool Failure 3 300 2RR1 PDC 8.50 3330 11300 7970 241.24 0.663 78.9 8 85 2775 490 1-1-NO-A-X-2-NO-TD TD Production Section WELL NAME:Beaver Creek Unit 24 LOCATION:Beaver Creek OPERATOR:Hilcorp Alaska, LLC AREA:Kenai Peninsula Borough MUD CO: RIG: Saxon 169 SPERRY JOB: AK-AM-0901663907 TD:9-Oct-2014 Baroid STATE:Alaska SPUD:22-Sep-2014 B i t R e c o r d . . * Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 800.00 21-Sep-2014 12:00 AM Current Pump & Flow Data: Max ROP ROP (ft/hr) Mud Data Depth MWD Summary Morning Report Report # 1 Customer: Well: Area: Location: Rig: Beaver Creek 24 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek Rig Activity: Saxon 196 Report For: Tools ConditionBit # 3.48.80 Size WOB Depth in / out 100% Gas In Air=10,000 UnitsConnection Min Comments RPM ECD (ppg) ml/30min API FL Background (max)Trip Average Mud Type Lst Type 53 Ss (current) Cement Chromatograph (ppm) C-5i C-5nC-3 Cht Silt C-4i C-4n YP (lb/100ft2) 8.80 24 hr Max Weight Hours GvlCoal cP 29 AK-AM-0090150915 Drilling PV Avg Gas Summary (ppb Eq) Spud Mud Tuff 24 Hour Progress: Date: Footage 11.0 Flow In (gpm) Flow In (spm) Job No.: Daily Charges: Total Charges: Jimmy Greco Yesterday's Depth: Current Depth: 0' TFABit Type Depth ShClyst 0' 0' Rigging Up Max @ ft Current Depth Time: Gallons/stroke Avg to C-2 SPP (psi) MBT 0' pH Units* Casing Summary Lithology (%)Siltst 190 in Set At Craig Amos / Jane Grundin 24 hr Recap: Begin Rigging up to drill top hole for BCU 24. Minimum (max) 907-283-1309Unit Phone: Maximum Report By:Logging Engineers: Size Grade (current) Cly C-1 . * (current) 0 0 Cly 0 C-1 Grade 907-283-1309Unit Phone: 0 Jane Grundin Maximum Report By:Logging Engineers: 0 (max) 0 Craig Amos / Jane Grundin 24 hr Recap: Finsihed rigging up. Drilled F/70' MD T/181' MD and lost returns. Gained returns and drilled ahead T/345' MD and circulated. POOH to P/U directional tools. Making up BHA and RIH at time of report.. Downhole Losses: 84 bbls 0 0 Minimum 0 0 Set At 0 0 Units* Casing Summary Lithology (%)Siltst 190 in 0' pH 0.942 0 0 0 0- 81.2 C-2 0 SPP (psi) Depth Time: 292'17.8 Gallons/stroke Avg to MBT 0 0' 345' 345' Max @ ft Current - 0' TFABit Type Depth ShClyst 228.0 Flow In (gpm) Flow In (spm) Job No.: Daily Charges: Total Charges: Jimmy Greco Yesterday's Depth: Current Depth: 24 Hour Progress: Date: 19.0 Footage 8.6 70' 0 Gas Summary (ppb Eq) Spud Mud344' TuffGvlCoal cP 41 AK-AM-0090150915 Drilling Suface PV Avg YP (lb/100ft2) 8.40 24 hr Max Weight Hours C-3 Cht Silt C-4i C-4n C-5i C-5n 000 0 Cement 0 Chromatograph (ppm) 0 Ss (current) Size Mud Type Lst Type 45 Average 00Background (max)Trip Min Comments RPM ECD (ppg) ml/30min API FL WOB Depth in / out 100% Gas In Air=10,000 Units-Connection ConditionBit # 1 3.9 12.25VM-3 8.85 Size 95% Rig Activity: - Saxon 169 Report For: Tools -- Morning Report Report # 2 Customer: Well: Area: Location: Rig: Beaver Creek 24 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek ROP ROP (ft/hr) 3.07 @ Mud Data Depth MWD Summary 22-Sep-2014 12:00 AM Current Pump & Flow Data: 0 Max 0 mg/l 500.00 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides . * Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 400.00 0 24-Sep-2014 12:00 AM Current Pump & Flow Data: 1864 Max ROP ROP (ft/hr) 3.07 @ Mud Data Depth MWD Summary Morning Report Report # 3 Customer: Well: Area: Location: Rig: Beaver Creek 24 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek 95% Rig Activity: - Saxon 169 Report For: Tools -- ConditionBit # 1 5.0 12.25VM-3 9.00 Size WOB Depth in / out 100% Gas In Air=10,000 Units6Connection Min Comments RPM ECD (ppg) ml/30min API FL 11Background (max)Trip Average 11 Mud Type Lst Type 55 Ss (current) Size Cement 0 Chromatograph (ppm) 0 C-5i C-5n 000 0 C-3 Cht Silt C-4i C-4n Drilling Suface Hole PV Avg YP (lb/100ft2) 8.401510' TuffGvlCoal cP 39 Weight Hours 8.0 70' 0 Gas Summary Spud Mud Job No.: Daily Charges: Total Charges: Jimmy Greco Yesterday's Depth: Current Depth: 24 Hour Progress: Date: AK-AM-0090150915 Depth ShClyst 2051.0 Flow In (gpm) Flow In (spm) 22.0 Footage (ppb Eq) 917' 249' TFABit Type to MBT 6 345' 1639' 1294' Max @ ft Current Time: 1449'56.1 Gallons/stroke Avg 24 hr Max 1479' 56.6 C-2 22 SPP (psi) 1584' pH 0.942 0 0 0 0 511 166 Units* Casing Summary Lithology (%)Siltst 170 in 1021 25 Set At Depth Craig Amos / Jane Grundin 0 0 Minimum 0 (max) 0 907-283-1309Unit Phone: 0 Jane Grundin Maximum Report By:Logging Engineers: Grade (current) 0 0 Cly 3710 C-1 24 hr Recap: RIH to bottom and began drilling. Drilled F/350' MD - T/1500' MD, encountering clay formation. Circulated and short tripped out to 340' MD. Tripped in T/1500'MD and pumped sweep. Returned to drilling, currently drilling ahead at time of report. Mas Gas: 22 units Downhole Losses: 0 bbls Geology: N/A . * (current) 0 0 Cly 20674 C-1 Grade 907-283-1309Unit Phone: 0 Jane Grundin Maximum Report By:Logging Engineers: 3 (max) 0 Craig Amos / Jane Grundin 0 0 Minimum 5426 429 Set At DepthUnits* Casing Summary Lithology (%)Siltst 66 in 3152' pH 0.942 0 0 0 02431' - C-2 163 SPP (psi)1820'150.5 Gallons/stroke Avg 24 hr Max 54 18 MBT 48 1639' 3200' 1561' Max @ ft Current Time: 2763' 249' TFABit Type to Depth ShClyst 1231.3 Flow In (gpm) Flow In (spm) 18.8 Footage (ppb Eq) Job No.: Daily Charges: Total Charges: Jimmy Greco Yesterday's Depth: Current Depth: 24 Hour Progress: Date: AK-AM-0090150915 7.6 70' 0 Gas Summary Spud Mud3200' TuffGvlCoal cP 22 Weight Hours Circulating BU PV Avg YP (lb/100ft2) 7.70 C-3 Cht Silt C-4i C-4n C-5i C-5n 000 0 Cement 0 Chromatograph (ppm) 0 Ss (current) Size Mud Type Lst Type 24 Average 575Background (max)Trip Min Comments RPM ECD (ppg) ml/30min API FL WOB Depth in / out 100% Gas In Air=10,000 Units163Connection ConditionBit # 1 8.0 12.25VM-3 9.40 Size 95% Rig Activity: - Saxon 169 Report For: Tools -- Morning Report Report # 3 Customer: Well: Area: Location: Rig: Beaver Creek 24 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek ROP ROP (ft/hr) 3.07 @ Mud Data Depth MWD Summary 25-Sep-2014 12:00 AM Current Pump & Flow Data: 1973 Max 0 mg/l 500.00 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides 24 hr Recap: Drilled ahead F/1690' MD T/3200' MD. Pumped sweep and begin short trip. Unable to pull on elevators, washed and reamed T/2200' MD, pulled on elevators T/1500' MD. Pumped sweep, circulating bottoms up at time of report. Mas Gas: 163 units Fluids: 0 bbls Geology: N/A . * C-1 (current) 0 0 Cly 0 40.0 Grade 0 0 907-283-1309Unit Phone: 0 Jane Grundin Maximum Report By:Logging Engineers: 0 0 Minimum 2 (max) 0 Set At Depth - Craig Amos / Jane Grundin 56 in 9 5/8' 0 Units* Casing Summary Lithology (%)Siltst - - C-2 13 SPP (psi)- Gallons/stroke Avg 24 hr Max - - 5 3200' 3200' 0' Max @ ft Current Time: - 85.0 to 7.6 MBT 3152' pH 0.942 0 18.8 3128' Footage (ppb Eq) 249' TFABit Type Current Depth: 24 Hour Progress: Date: AK-AM-0090150915 Depth ShClyst - Flow In (gpm) Flow In (spm) C-3 Job No.: Daily Charges: Total Charges: James Sweetsir Yesterday's Depth: 3200' TuffGvlCoalChtSilt Size 70' cP 17 Weight Hours 25.47 WOB Surface Casing R/U Cementers PV Avg YP (lb/100ft2) 7.20 C-5n 000 0 0 Gas Summary Cement 0 C-4i C-4n C-5i Chromatograph (ppm) 0 0 0 0 Ss (current) Mud Type Lst Type 3186' 14 Average 13Background (max)Trip Min Comments RPM ECD (ppg) ml/30min API FL 27.0 Depth in / out 100% Gas In Air=10,000 Units-Connection Condition 1-1-WT-AE-I-NO-TD Bit # 1 8.3 12.25VM-3 9.50 Size Spud Mud 3200' 95% Rig Activity: - Saxon 169 Report For: Tools -- Morning Report Report # 5 Customer: Well: Area: Location: Rig: Beaver Creek 24 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek ROP ROP (ft/hr) 3.07 @ Mud Data Depth MWD Summary 26-Sep-2014 12:00 AM Current Pump & Flow Data: - Max 0 mg/l 550.00 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides 24 hr Recap: CBU, TOH to surface. L/D BHA and R/U to run casing. Run 9 5/8' surface casing, CBU every 1,000'. Land casing at 3186' MD and R/U cementers. PT lines at time of report. Mas Gas: 13 units Fluids: 0 bbls Geology: N/A . * (current) Surface 0 0 Cly 20 C-1 82.0 X-56 Grade 907-283-1309Unit Phone: 0 Jane Grundin Maximum Report By:Logging Engineers: 0 (max) 0 Jake Hansen / Jane Grundin 0 0 Minimum L-80 0 0 Set At DepthUnits* Casing Summary Lithology (%)Siltst 44 in 16.00'' 9 5/8" 1584' pH 0.942 0 0 0 0- - C-2 6 SPP (psi)-- Gallons/stroke Avg 24 hr Max - - MBT 0 3200' 3200' 0' Max @ ft Current Time: - 249' TFABit Type 85.0 to Depth ShClyst - Flow In (gpm) Flow In (spm) 5.5 3128' Footage (ppb Eq) Job No.: Daily Charges: Total Charges: James Sweetsir Yesterday's Depth: Current Depth: 24 Hour Progress: Date: AK-AM-0090150915 6.3 72' 3200' 0 Gas Summary KCL3200' TuffGvlCoal cP 9 40.0 Weight Hours Testing BOP PV Avg YP (lb/100ft2) 8.10 C-3 25.47 Cht Silt C-4i C-4n C-5i C-5n 000 0 Cement 0 Chromatograph (ppm) 0 Ss (current) Size Mud Type Lst Type 3186' 80' 16 Average 60Background (max)Trip Min Comments BTC RPM ECD (ppg) ml/30min API FL 27.0 WOB Conductor Depth in / out 100% Gas In Air=10,000 Units-Connection Condition 1-1-WT-AE-I-NO-TD Bit # 1 6.9 12.25VM-3 9.60 Size 95% Rig Activity: - Saxon 169 Report For: Tools -- Morning Report Report # 6 Customer: Well: Area: Location: Rig: Beaver Creek 24 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek Weld ROP ROP (ft/hr) 3.07 @ Mud Data Depth MWD Summary 27-Sep-2014 12:00 AM Current Pump & Flow Data: - Max 0 mg/l 27000.00 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides 24 hr Recap: Begin pumping cement w/ 230 bbls lead cement and 50 bbls tail cement. Did not bump plug but floats held. Dumped 78.5 bbls cement into cellar. R/D cementers and diverter. Nippled up BOP and prep for testing. Removing spud mud and cleaning pits at time of report. Mas Gas: 6 units Downhole Losses: 0 bbls Geology: N/A . * Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 29000.00 0 28-Sep-2014 12:00 AM Current Pump & Flow Data: - Max Weld ROP ROP (ft/hr) 3.07 @ Mud Data Depth MWD Summary Morning Report Report # 7 Customer: Well: Area: Location: Rig: Beaver Creek 24 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek 95% Rig Activity: - Saxon 169 Report For: Tools Gamma/Res -- Bit # 1 4.8 12.25VM-3 9.30 Size Depth in / out 100% Gas In Air=10,000 Units-Connection Condition 1-1-WT-AE-I-NO-TD Min Comments BTC RPM ECD (ppg) ml/30min API FL 27.0 Background (max)Trip Average - Mud Type Lst Type 3186' 80' 17 Ss (current) Chromatograph (ppm) 0 Cement 0 C-4i C-4n C-5i C-5n 000 0 RIH to Drill Production PV Avg YP (lb/100ft2) 8.60 cP 8 40.0 Weight Hours 25.47 WOB Conductor KCL 3200' 3200' TuffGvlCoalChtSilt 2 Size 72' 3200' 0 Gas Summary PDC C-3 Job No.: Daily Charges: Total Charges: James Sweetsir Yesterday's Depth: Current Depth: 24 Hour Progress: Date: AK-AM-0090150915 Depth ShClyst - Flow In (gpm) Flow In (spm) 4.0 3128' Footage (ppb Eq) 249' TFABit Type 85.0 to 5.8 MBT 0 3200' 3200' 0' Max @ ft Current Time: -- Gallons/stroke Avg 24 hr Max - - - - C-2 0 SPP (psi) 3200' pH 0.942 0 0 0 0 8.5 Units* Casing Summary Lithology (%)Siltst 46 in 16.00'' 9 5/8" 0.663 0 0 Set At Depth - Jake Hansen / Jane Grundin 0 0 Minimum 0 (max) 0 0 907-283-1309Unit Phone: 0 Jane Grundin Maximum Report By:Logging Engineers: 82.0 X-56 Grade L-80 (current) Surface 0 0 Cly 0 C-1 24 hr Recap: Finished BOP test and mixing KCL mud. P/U BHA, L/D extra HWDP and TIH on singles. Preparing to slip and cut drill line at time of report. Mas Gas: 0 units Fluids: 0 bbls Geology: N/A . * C-1 (current) Surface 23 9 Cly 39114 82.0 X-56 Grade L-80 8 2 907-283-1309Unit Phone: 0 Jane Grundin Maximum Report By:Logging Engineers: 0 0 Minimum 0 (max) 83 Set At Depth 3200' Jake Hansen / Jane Grundin 3275' 45 in 16.00'' 9 5/8" 0.663 0 8.5 Units* Casing Summary Lithology (%)Siltst 3289' 0.0 C-2 313 SPP (psi)7.3 Gallons/stroke Avg 24 hr Max - - 71 3200' 3330' 130' Max @ ft Current Time: 3309' 50 to 5.1 MBT 3330' pH 0.663 0 3.5 130' Footage (ppb Eq) 249' TFABit Type Current Depth: 24 Hour Progress: Date: AK-AM-0090150915 Depth ShClyst 224.1 Flow In (gpm) Flow In (spm) PDC C-3 Job No.: Daily Charges: Total Charges: James Sweetsir Yesterday's Depth: 3330' 3331' TuffGvlCoalChtSilt 2RR1 Size 3200' cP 9 40.0 Weight Hours 1.02 WOB Conductor Drilling Ahead 8.5" Hole PV Avg YP (lb/100ft2) 9.30 C-5n 000 0 0 Gas Summary Cement 0 C-4i C-4n C-5i Chromatograph (ppm) 0 0 0 10545 Ss (current) Mud Type Lst 100 Type 3186' 80' 16 Average 6Background (max)Trip Min Comments BTC RPM ECD (ppg) ml/30min API FL 4 Depth in / out 100% Gas In Air=10,000 Units136Connection Condition 1-1-WT-A-X-I-NO-DTF Bit # 2 5.3 8.5PDC 9.40 Size KCL 3330' 95% Rig Activity: - Saxon 169 Report For: Tools Gamma/Res -- Morning Report Report # 8 Customer: Well: Area: Location: Rig: Beaver Creek 24 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek Weld ROP ROP (ft/hr) 3.07 @ Mud Data Depth MWD Summary 29-Sep-2014 12:00 AM Current Pump & Flow Data: - Max 0 mg/l 32000 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides 24 hr Recap: Drilled cement and 20' rat hole. Conducted FIT to 11.8 ppg EMW. Drilled ahead T/3,330 and stopped for MWD tool failure. CBU, pumped dry job, TOOH for MWD. L/D BHA and P/U new BHA. RIH on singles and begin to drill ahead at time of report. Mas Gas: 313 units Fluids: 0 bbls Geology: 100% Sandstone :ltgy - gry, pal yel, brn, grn, trans, opq, vfn grn, lse unconsol, tr slst, tr coal, tr glauc . . * Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 33500 30-Sep-2014 12:00 AM Current Pump & Flow Data: - Max Depth MWD Summary ROP ROP (ft/hr) 3.07 @ Mud Data Morning Report Report # 9 Customer: Well: Area: Location: Rig: Beaver Creek 24 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek 95% Rig Activity: - Saxon 169 Report For: Tools Gamma/Res -- Bit # 2 300.0 8.5PDC 9.30 Size 3330' 100% Gas In Air=10,000 Units102Connection 0 Min Comments BTC RPM ECD (ppg) ml/30min API FL 4 Background (max)Trip Average 0 Mud Type Lst 20 Type 3186' 80' 16 Ss (current) Chromatograph (ppm) 0 0 0 0 C-4i C-4n C-5i C-5n 000 0 0 Gas Summary Avg YP (lb/100ft2) 9.20 Condition 1-1-WT-A-X-I-NO-DTF Weld WOB Conductor RIH from short trip PV Depth in / out 3200' cP 12 40.0 Weight Hours 1.02 TuffGvlCoalChtSilt 2RR1 Size Cement C-3 Job No.: Daily Charges: Total Charges: James Sweetsir Yesterday's Depth: 3330' Current Depth: 24 Hour Progress: Date: AK-AM-0090150915 Depth ShClyst 794.4 Flow In (gpm) Flow In (spm) 4.5 130' Footage (ppb Eq) 249' TFABit Type PDC 4830' 50 to 4.4 MBT 4830' pH 0.663 0 39 3200' 4830' 1630' Max @ ft Current Time: 3341' SPP (psi)106.4 Gallons/stroke Avg 24 hr Max - - 3875' 0.0 C-2 112 9 5/8" 0.663 0 8.5 Units* Casing Summary Lithology (%)Siltst Jake Hansen / Jane Grundin 48 in 16.00'' Minimum 3 (max) 89784047' 9604 1 907-283-1309Unit Phone: 0 Jane Grundin Maximum Report By:Logging Engineers: X-56 Grade L-80 Set At Depth Cly 15370 82.0 8 0 0 80 C-1 (current) Surface 23 9 24 hr Recap: Drill ahead F/3,331' MD - T/3,955' MD. Pump sweep, drill ahead T/4,830' MD. Pump sweep, TOH to shoe for wiper trip. TIH on singles, back to bottom at time of report. Drilling ahead. Mas Gas: 112 units Fluids: 0 bbls Geology: Siltstone : lt gry, frm, pr ind, blky, tf, sl cly, tr Tf. Sand : lt gry, brn, wh, trans-transp, f gr, sbrnd, wl srt, calc, slty. . * (current) Surface 83 0 82.0 8 0 0 C-1 Set At Depth Cly 113649 C-3 13 907-283-1309Unit Phone: 0 Jane Grundin Maximum Report By:Logging Engineers: Minimum 3 (max) 27895270' 8250 Jake Hansen / Jane Grundin 59 in 16.00'' 0.0 C-2 1000 9 5/8" 0.6638.5 24 hr Max 0 0 5605'0 L-80 63 4830' 6320' 1490' Max @ ft Current Time: 4836' SPP (psi) 4.7 MBT 6320' pH 0.663 0 Siltst X-56 Grade (ppb Eq) 249' TFABit Type PDC 6321' Current Depth: 24 Hour Progress: Date: AK-AM-0090150915 Depth ShClyst 770.6 Flow In (gpm) Flow In (spm) Job No.: Daily Charges: Total Charges: James Sweetsir Yesterday's Depth: Short tripRig Activity: Cht Silt 2RR1 Size Cement Casing Summary Lithology (%) Weight Hours 1.02 TuffGvlCoal 50 Conductor PV Depth in / out 3200' cP 14 3330' 4.5 130' Footage YP (lb/100ft2) 8.80 Condition 1-1-WT-A-X-I-NO-DTF Weld WOB 40.0 C-5n 000 0 0 Gas Summary 0 C-4i C-4n C-5i Chromatograph (ppm) 0 0 0 Ss (current) Units* Mud Type Lst 100 Type 3186' 80' 21 Average 0Background (max)Trip Comments BTC RPM ECD (ppg) ml/30min API FL 4 Avg 100% Gas In Air=10,000 Units290Connection 0 Bit # 2 4.5 8.5PDC 9.25 Size KCL 3330' Saxon 169 Report For: Tools Gamma/Res -- Min ROP Avg Morning Report Report # 10 Customer: Well: Area: Location: Rig: Beaver Creek 24 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek ROP (ft/hr) 3.07 @ Mud Data to 59.6 Gallons/stroke - Depth MWD Summary 1-Oct-2014 12:00 AM Current Pump & Flow Data: 0 Max 95% mg/l 29500 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides 24 hr Recap: RIH T/4,830' MD, drill ahead T/6,321' MD. Pump sweep, conducting short trip at time of report. Mas Gas: 1000 units Fluids: 0 bbls Geology: light grey, soft, very fine to course grain, occasional very course Quartz grains, sub round, poorly sorted, poor consolidation, silty matrix, tuffaceous, trace Coal, trace Siltstone.. . * (current) Surface 105 9 82.0 8 0 0 40 C-1 Set At Depth Cly 152654 C-3 30 15 907-283-1309Unit Phone: 0 Jane Grundin Maximum Report By:Logging Engineers: Minimum 5 (max) 17456528' 13503 Jake Hansen / Jane Grundin 57 in 16.00'' 0.0 C-2 1343 9 5/8" 0.6638.5 24 hr Max 475 155 6606'0 L-80 95 6320' 7260' 940' Max @ ft Current Time: 6891' SPP (psi) 4.6 MBT 7260' pH 0.663 0 Siltst X-56 Grade (ppb Eq) 249' TFABit Type PDC 7198' Current Depth: 24 Hour Progress: Date: AK-AM-0090150915 Depth ShClyst 199.9 Flow In (gpm) Flow In (spm) Job No.: Daily Charges: Total Charges: James Sweetsir Yesterday's Depth: Drilling Ahead 8 1/2" HoleRig Activity: Cht Silt 2RR1 Size Cement Casing Summary Lithology (%) Weight Hours 1.02 TuffGvlCoal 50 Conductor PV Depth in / out 3200' cP 15 3330' 4.0 130' Footage YP (lb/100ft2) 9.10 Condition 1-1-WT-A-X-I-NO-DTF Weld WOB 40.0 C-5n 000 0 0 Gas Summary 0 C-4i C-4n C-5i Chromatograph (ppm) 9 0 0 Ss (current) Units* Mud Type Lst 30 Type 3186' 80' 19 Average -Background (max)Trip Comments BTC RPM ECD (ppg) ml/30min API FL 4 Avg 100% Gas In Air=10,000 Units274Connection 0 Bit # 2 4.5 8.5PDC 9.30 Size KCL 3330' Saxon 169 Report For: Tools Gamma/Res -- Min ROP Avg Morning Report Report # 11 Customer: Well: Area: Location: Rig: Beaver Creek 24 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek ROP (ft/hr) 3.07 @ Mud Data to 37.7 Gallons/stroke - Depth MWD Summary 1-Oct-2014 12:00 AM Current Pump & Flow Data: 1795 Max 95% mg/l 33000 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides 24 hr Recap: Completed wiper trip T/4,800' MD. Drilled ahead T/7,138' MD and pumped sweep. Drilled ahead, 7,260' MD at time of report. Mas Gas: 1343 units Fluids: 0 bbls Geology: 40% Sltst: lt gry, sft, mass, amor, pr ind, sd, tf, abdnt Qtz flk; 30% Ss: gry, sft, f-crs gr, sb rnd, pr srt, pr consol, slt Mtrx, com lrg Qtz flk, tf; 30% Sh: med brn, sft, pr ind, flky, ea. . * Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 32000 2-Oct-2014 12:00 AM Current Pump & Flow Data: 2056 Max 95% Depth MWD Summary ROP (ft/hr) 3.07 @ Mud Data to 28.3 Gallons/stroke - Morning Report Report # 12 Customer: Well: Area: Location: Rig: Beaver Creek 24 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek Saxon 169 Report For: Tools Gamma/Res -- Min ROP Avg Bit # 2 4.6 8.5PDC 9.30 Size KCL 3330' 100% Gas In Air=10,000 Units152Connection 60 3 RPM ECD (ppg) ml/30min API FL 4 Avg Background (max)Trip Average 46 Mud Type Lst Type 3186' 80' 20 Ss (current) Units* Chromatograph (ppm) 20 0 0 0 C-4i C-4n C-5i C-5n 000 0 0 Gas Summary YP (lb/100ft2) 9.50 Condition 1-1-WT-A-X-I-NO-DTF Weld WOB 40.0 PV Depth in / out 3200' cP 17 3330' 3.8 130' Footage 1.02 TuffGvlCoal 50 Conductor Comments BTC Cement Casing Summary Lithology (%) Weight Job No.: Daily Charges: Total Charges: James Sweetsir Yesterday's Depth: Drilling Ahead 8 1/2" HoleRig Activity: Current Depth: 24 Hour Progress: Date: AK-AM-0090150915 Depth ShClyst 231.6 Flow In (gpm) Flow In (spm) (ppb Eq) 249' TFABit Type PDC 7910' 2RR1 Size Hours 4.6 MBT 7965' pH 0.663 6 Siltst X-56 Grade 89 7260' 7965' 705' Max @ ft Current Time: 7507' SPP (psi) 24 hr Max 480 156 7930' 10 0 L-80 76.3 C-2 525 9 5/8" 0.6638.5 Jake Hansen / Jane Grundin 63 in 16.00'' Minimum 5 (max) 61257296' 13952 52 907-283-1309Unit Phone: 0 Jane Grundin Maximum Report By:Logging Engineers: Set At Depth Cly 102984 C-3 Cht Silt 82.0 11 0 0 30 C-1 (current) Surface 67 0 24 hr Recap: Drilled ahead T/7,506' MD, pumped sweep. Wiper trip T/6,198' MD with over pull @ 6,440' MD and 6,410' MD. Back reamed at both depths. Ran back to bottom on singles, drilling ahead, 7,965' MD at time of report. Mas Gas: 525 units Fluids: 0 bbls Geology: 60% Claystone : gry, frm, tky, pli, slt, hygtd; 30% Siltstone : med gry, sft, amor, pr ind, tf; 10% Coal : dk brn, sft-frm, mod ind, flky, ea. . * (current) Surface 76 8 82.0 6 0 0 60 C-1Depth Cly 137136 C-3 Cht Silt 0 907-283-1309Unit Phone: 0 Jane Grundin Maximum Report By:Logging Engineers: Minimum 22 (max) 57398320' 14737 Jake Hansen / Jane Grundin 65 in 16.00'' 0.0 C-2 714 9 5/8" 0.6638.5 24 hr Max 0 0 8365'2 L-80 111 7965' 8502' 537' Max @ ft Current Time: 8380' SPP (psi) MBT 8461' pH 0.663 10 Siltst X-56 Grade Bit Type PDC 8502' 2RR1 Size Hours Set At Depth ShClyst 319.2 Flow In (gpm) Flow In (spm) (ppb Eq) 249' TFA Yesterday's Depth: Short Trip to ShoeRig Activity: Current Depth: 24 Hour Progress: Date: AK-AM-0090150915 Casing Summary Lithology (%) Weight Job No.: Daily Charges: Total Charges: James Sweetsir 1.02 TuffGvlCoal 50 Conductor Comments BTC Cement PV Depth in / out 3200' cP 16 3330' 3.5 130' Footage YP (lb/100ft2) 10.40 Condition 1-1-WT-A-X-I-NO-DTF Weld WOB 40.0 40 C-5n 000 0 0 Gas Summary 0 C-4i C-4n C-5i Chromatograph (ppm) 37 5 0 Ss (current) Units* Mud Type Lst Type 3186' 80' 20 Average 4Background (max)Trip RPM ECD (ppg) ml/30min API FL 4 Avg 4.4 100% Gas In Air=10,000 Units125Connection 6 Bit # 2 5.1 8.5PDC 9.40 Size KCL 3330' Saxon 169 Report For: Tools Gamma/Res -- Min ROP Avg Morning Report Report # 13 Customer: Well: Area: Location: Rig: Beaver Creek 24 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek ROP (ft/hr) 3.07 @ Mud Data to 41.7 Gallons/stroke - Depth MWD Summary 3-Oct-2014 12:00 AM Current Pump & Flow Data: 0 Max 95% mg/l 33000 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides 24 hr Recap: Drilled ahead T/8502' MD, pumped sweep. TOOH, pumping at 6184' MD. Pumped and reamed T/5555' MD, back reaming out at time of report. Mas Gas: 714 units Fluids: 0 bbls Geology: 60% Siltstone : med gry, occ brwn, sft occ frm, amor, pr ind, tf, sd; 40% Claystone : med gry, sft, tky, pr ind, pli, slt, non swlg, SHOW: no vis fluor, brt yel- brt grn crsh ct, brt yel res rng. . * (current) Surface 83 44 82.0 22 0 0 80 C-1Depth Cly 138430 C-3 Cht Silt TuffGvl 31 907-283-1309Unit Phone: 0 Jane Grundin Maximum Report By:Logging Engineers: Minimum 8 (max) 707068697' 31207 Jake Hansen / Jane Grundin 58 in 16.00'' 6.0 C-2 686 9 5/8" 0.6638.5 24 hr Max 142 437 8672' 10 15 L-80 150 8502' 8871' 369' Max @ ft Current Time: 8702' SPP (psi) MBT 8770' pH 0.663 0 Siltst X-56 Grade PDC 8840' 2RR1 Size Hours Set At Casing Summary Bit # 2 Depth ShClyst 114.7 Flow In (gpm) Flow In (spm) (ppb Eq) 249' TFA Yesterday's Depth: Drilling Ahead 8 1/2" HoleRig Activity: Current Depth: 24 Hour Progress: Date: AK-AM-0090150915 Lithology (%) Weight Job No.: Daily Charges: Total Charges: James Sweetsir 1.02 Coal 50 Conductor Comments BTC Cement PV Depth in / out 3200' cP 19 3330' 3.5 130' Footage YP (lb/100ft2) 10.40 Condition 1-1-WT-A-X-I-NO-DTF Weld WOB 40.0 C-5n 001 5 0 Gas Summary 0 C-4i C-4n C-5i Chromatograph (ppm) 39 21 0 Ss (current) Units* Mud Type Lst Type 3186' 80' 22 Average 65Background (max)Trip RPM ECD (ppg) ml/30min API FL 4 Avg 4.3 100% Gas In Air=10,000 Units417Connection 10 9 5.1 8.5PDC 9.40 Size KCL 3330' Bit Type Saxon 169 Report For: Tools Gamma/Res -- Min ROP Avg Morning Report Report # 14 Customer: Well: Area: Location: Rig: Beaver Creek 24 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek ROP (ft/hr) 3.07 @ Mud Data to 14.9 Gallons/stroke - Depth MWD Summary 4-Oct-2014 12:00 AM Current Pump & Flow Data: 1785 Max 95% mg/l 33500 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides 24 hr Recap: Back reamed T/5086' MD, finished TOOH on elevators to shoe. Slipped and cut drill line, serviced rig, RIH on singles T/4525' MD. RIH on stands T/4632' MD, washed and reamed T/5301' MD, finished TIH on elevators. RIH T/8429 and tagged fill, washed to bottom. Drilling ahead at time of report. Mas Gas: 686 units Fluids: 66 bbls lost downhole Geology: 80 % Siltstone : lt brn, lt gry-med gry, sft-frm, amor-blky, mod ind, tf; SHOW: n vis fluor, slw stmg bl wh ct, 30% dl yel crsh ct, n res rng. 20% Claystone : med gry, frm, tky, mod ind, pli, non swlg; 10% Coal : dk brn, sft-frm, mod ind, flky, ea. . * Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 32000 5-Oct-2014 12:00 AM Current Pump & Flow Data: 2184 Max 95% Depth MWD Summary ROP (ft/hr) 3.07 @ Mud Data to 24.7 Gallons/stroke - Morning Report Report # 15 Customer: Well: Area: Location: Rig: Beaver Creek 24 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek Saxon 169 Report For: Tools Gamma/Res -- Min ROP Avg 5.6 8.5PDC 9.65 Size KCL 3330' Bit Type 100% Gas In Air=10,000 Units5127Connection 12 RPM ECD (ppg) ml/30min API FL 4 Avg 3.8 Background (max)Trip Average 76 Mud Type Lst Type 3186' 80' 21 Ss (current) Units* Chromatograph (ppm) 337 11 0 4 C-4i C-4n C-5i C-5n 001 3 7 Gas Summary YP (lb/100ft2) 9.90 Condition 1-1-WT-A-X-I-NO-DTF Weld WOB 40.0 PV Depth in / out 3200' cP 19 3330' 3.5 130' Footage Coal 50 Conductor Comments BTC Cement Lithology (%) Weight Job No.: Daily Charges: Total Charges: James Sweetsir 1.02 Yesterday's Depth: Short Wiper TripRig Activity: Current Depth: 24 Hour Progress: Date: AK-AM-0090150915 Depth ShClyst 1313.0 Flow In (gpm) Flow In (spm) (ppb Eq) 249' TFA PDC 9478' 2RR1 Size Hours Set At Casing Summary Bit # 2 MBT 9392' pH 0.663 0 Siltst X-56 Grade 152 8871' 9477' 606' Max @ ft Current Time: 9377' SPP (psi) 24 hr Max 448 146 9338' 90 54 L-80 0.0 C-2 4142 9 5/8" 0.6638.5 Jake Hansen / Jane Grundin 64 in 16.00'' Minimum 6 (max) 2979469' 30234 45 907-283-1309Unit Phone: 15 Jane Grundin Maximum Report By:Logging Engineers: Depth Cly 452628 C-3 Cht Silt TuffGvl 82.0 21 0 0 10 C-1 (current) Surface 436 11 24 hr Recap: Healed the hole and continued drilling ahead T/9445' MD. Short tripped F/9478' MD T9066' MD on elevators, having to screw in and pump through tight spots. Back reamed F/8945' MD T/8870' MD. Back reaming out for short wiper trip at time of report. Mas Gas: 4142 units Fluids: 75 bbls lost downhole Geology: 90% Coal : blk, hrd, splty, vit; SHOW: n stn, n vis fluor, slw strmg brt bl wh ct, mod dl wh fluor res rng, thn strw NL res rng; 10% Siltstone : lt brn, lt gry, frm w/occ hrd, blky, fri, tf, sd. . * (current) Surface 976 9 82.0 96 0 7 30 C-1Depth Cly 743849 C-3 Sd Silt TuffGvl 157 907-283-1309Unit Phone: 0 Jane Grundin Maximum Report By:Logging Engineers: Minimum 6 (max) 98939720' 101900 Jake Hansen / Jane Grundin 64 in 16.00'' 41.0 C-2 5597 9 5/8" 0.6638.5 24 hr Max 431 140 10039' 10 27 L-80 406 9477' 10127' 650' Max @ ft Current Time: 9477' SPP (psi) MBT 10075' pH 0.663 79 Siltst X-56 Grade PDC 10121' 2RR1 Size Hours Set At Casing Summary Bit # 2 Depth ShClyst 396.1 Flow In (gpm) Flow In (spm) (ppb Eq) 249' TFA Yesterday's Depth: Drilling Ahead 8 1/2" HoleRig Activity: Current Depth: 24 Hour Progress: Date: AK-AM-0090150915 Lithology (%) Weight Job No.: Daily Charges: Total Charges: James Sweetsir 1.02 Coal 50 Conductor Comments BTC Cement PV Depth in / out 3200' cP 21 3330' 35.0 130' Footage YP (lb/100ft2) 9.10 Condition 1-1-WT-A-X-I-NO-DTF Weld WOB 40.0 C-5n 000 0 27 Gas Summary 0 C-4i C-4n C-5i 10 Chromatograph (ppm) 445 0 0 Ss (current) Units* Mud Type Lst 30 20 Type 3186' 80' 23 Average -Background (max)Trip RPM ECD (ppg) ml/30min API FL 4 Avg 3.4 100% Gas In Air=10,000 Units7858Connection 38 7.7 8.5PDC 10.10 Size KCL 3330' Bit Type Saxon 169 Report For: Tools Gamma/Res -- Min ROP Avg Morning Report Report # 16 Customer: Well: Area: Location: Rig: Beaver Creek 24 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek ROP (ft/hr) 3.07 @ Mud Data to 26.1 Gallons/stroke - Depth MWD Summary 7-Oct-2014 12:00 AM Current Pump & Flow Data: 2421 Max 95% mg/l 32500 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides 24 hr Recap: Complete wiper trip and RIH T/9476' MD. Encountered 24' of fill and pumped sweep. Drill ahead F/9900' MD - T/10066' MD. Saw 60% flow increase and 5592U FGP, 4250U CG. Circulated and monitored while weighting up mud T/10.1 ppg. Drill ahead F/10066'MD - T/10127' MD, drilling ahead at time of report. Mas Gas: 5597 units Fluids: 0 bbls lost downhole Geology: 30% Sandstone : lt gry-tn, frm, f-c gr, sb rnd, mod-pr srt, pr consol, tf Mtrx; SHOW: n stn, n vis fluor, slw stmg brt wh ct, n NL res rng. 30% Siltstone : tan-gry, frm, blky, fri. 20%Sand : trans-transp, f-c gr, mod srt, sb rnd. 10% Tuff : wht, sft, amor, sd. 10% Coal : blk, sft-frm, mod ind, Splin, brit, ea-vit. . * Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 31500 7-Oct-2014 12:00 AM Current Pump & Flow Data: 0 Max 95% Depth MWD Summary ROP (ft/hr) 3.07 @ Mud Data to 17.9 Gallons/stroke - Morning Report Report # 17 Customer: Well: Area: Location: Rig: Beaver Creek 24 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek Saxon 169 Report For: Tools Gamma/Res -- Min ROP Avg 7.9 8.5PDC 10.10 Size KCL 3330' Bit Type 100% Gas In Air=10,000 Units606Connection 14 RPM ECD (ppg) ml/30min API FL 4 Avg 3.3 Background (max)Trip Average 80 Mud Type Lst 40 10 Type 3186' 80' 20 Ss (current) Units* Chromatograph (ppm) 74 0 0 0 C-4i C-4n C-5i C-5n 000 0 0 Gas Summary YP (lb/100ft2) 9.10 Condition 1-1-WT-A-X-I-NO-DTF Weld WOB 40.0 PV Depth in / out 3200' cP 21 3330' 3.5 130' Footage Coal 50 Conductor Comments BTC Cement Lithology (%) Weight Job No.: Daily Charges: Total Charges: James Sweetsir 1.02 Yesterday's Depth: Drilling Ahead 8 1/2" HoleRig Activity: Current Depth: 24 Hour Progress: Date: AK-AM-0090150915 Depth ShClyst 542.7 Flow In (gpm) Flow In (spm) (ppb Eq) 249' TFA PDC 10550' 2RR1 Size Hours Set At Casing Summary Bit # 2 MBT 10506' pH 0.663 0 Siltst X-56 Grade 145 10127' 10565' 438' Max @ ft Current Time: 10549' SPP (psi) 24 hr Max 0 0 10442' 20 0 L-80 0.0 C-2 699 9 5/8" 0.6638.5 Jake Hansen / Jane Grundin 61 in 16.00'' Minimum 6 (max) 5710285' 30212 48 907-283-1309Unit Phone: 0 Jane Grundin Maximum Report By:Logging Engineers: Depth Cly 165508 C-3 Sd Silt TuffGvl 82.0 34 0 0 30 C-1 (current) Surface 195 0 24 hr Recap: Drill ahead F/10120' MD - T/10548' MD, pump sweep. Short trip F/10548' MD - T/9400' MD. Tight spots occured btwn 10117' MD - 9980' MD and 9790' MD - 9400' MD. RIH washing out 48' of fill. CBU 989U gas. Currently at 10566' MD and drilling ahead at time of report. Mas Gas: 699 units Fluids: 0 downhole losses Geology: 40% Sandstone : lt gry, sft, f-c gr, sb rnd, mod-pr srt, pr consol, tf Mtrx; SHOW: n stn, n vis fluor, slw stmg dl wt ct, n res rng; 30% Siltstone : tan-brnsh gry, frm, blky, fri, tf, sd; 20% Coal : blk, frm-hrd, blky, flky, ang, vit; 10% Sand : trans-transp, f-c gr, pr srt, sb rnd. . * (current) Surface 28 34 82.0 22 17 0 C-1Depth Cly 1033 C-3 Sd Silt TuffGvl 18 907-283-1309Unit Phone: 0 Jane Grundin Maximum Report By:Logging Engineers: Minimum 5 (max) 102010782' 4198 Jake Hansen / Jane Grundin 10612' 63 in 16.00'' 19.0 C-2 1048 9 5/8" 0.6638.5 24 hr Max 142 435 10723' 10 12 L-80 90 10565' 11170' 605' Max @ ft Current Time: 10921' SPP (psi) MBT 11130' pH 0.663 14 Siltst X-56 Grade 10 PDC 11133' 2RR1 Size Hours Set At Casing Summary Bit # 2 Depth ShClyst 236.0 Flow In (gpm) Flow In (spm) (ppb Eq) 249' TFA Yesterday's Depth: Drilling Ahead 8 1/2" HoleRig Activity: Current Depth: 24 Hour Progress: Date: AK-AM-0090150915 Lithology (%) Weight Job No.: Daily Charges: Total Charges: James Sweetsir 1.02 Coal 50 Conductor Comments BTC Cement PV Depth in / out 3200' cP 22 3330' 4.0 130' Footage YP (lb/100ft2) 10.20 Condition 1-1-WT-A-X-I-NO-DTF Weld WOB 40.0 C-5n 000 16 0 Gas Summary 0 C-4i C-4n C-5i Chromatograph (ppm) 16 18 0 Ss (current) Units* Mud Type Lst 80 Type 3186' 80' 21 Average -Background (max)Trip RPM ECD (ppg) ml/30min API FL 4 Avg 3.2 100% Gas In Air=10,000 Units102Connection 4 8.1 8.5PDC 10.10 Size KCL 3330' Bit Type Saxon 169 Report For: Tools Gamma/Res -- Min ROP Avg Morning Report Report # 18 Customer: Well: Area: Location: Rig: Beaver Creek 24 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek ROP (ft/hr) 3.07 @ Mud Data to 47.1 Gallons/stroke - Depth MWD Summary 8-Oct-2014 12:00 AM Current Pump & Flow Data: 2403 Max 95% mg/l 33000 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides 24 hr Recap: Drilling ahead F/10566' MD - T/11170' MD, drilling ahead at time of report. Mas Gas: 1048 units Fluids: 0 downhole losses Geology: 80% Sandstone : lt gry, sft, f-c gr, sb rnd, mod-wl srt, pr consol, tf Mtrx; SHOW: n stn, n vis fluor, mod stmg brt wt ct, n res rng; 10% Siltstone : wt, tan-brnsh gry, frm, blky, fri, tf, sd, sl ind; 10% Coal : blk, frm-hrd, blky, flky, ang, vit. . * Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 34000 9-Oct-2014 12:00 AM Current Pump & Flow Data: 1799 Max 95% Depth MWD Summary ROP (ft/hr) 3.07 @ Mud Data to 29.0 Gallons/stroke - Morning Report Report # 19 Customer: Well: Area: Location: Rig: Beaver Creek 24 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek Saxon 169 Report For: Tools Gamma/Res -- Min ROP Avg 8.1 8.5PDC 10.15 Size KCL 3330' Bit Type 100% Gas In Air=10,000 Units35Connection 12 RPM ECD (ppg) ml/30min API FL 4 Avg 3.2 Background (max)Trip Average 498 Mud Type Lst 20 Type 3186' 80' 23 Ss (current) Units* Chromatograph (ppm) 13 13 0 0 C-4i C-4n C-5i C-5n 0100 13 0 Gas Summary YP (lb/100ft2) 10.70 Condition 1-1-WT-A-X-I-NO-DTF Weld WOB 40.0 PV Depth in / out 3200' cP 20 3330' 4.0 130' Footage Coal 50 Conductor Comments BTC Cement Lithology (%) Weight Job No.: Daily Charges: Total Charges: Jimmy Greco 1.02 Yesterday's Depth: Back Reaming out of HoleRig Activity: Current Depth: 24 Hour Progress: Date: AK-AM-0090150915 Depth ShClyst 63.9 Flow In (gpm) Flow In (spm) (ppb Eq) 249' TFA PDC 11300' 2RR1 Size Hours Set At Casing Summary Bit # 2 MBT 11300' pH 0.663 15 Siltst X-56 Grade 50 30 11170' 11300' 130' Max @ ft Current Time: 11299' SPP (psi) 24 hr Max 137 423 11282' 10 13 L-80 0.0 C-2 151 9 5/8" 0.6638.5 Jake Hansen / Jane Grundin 60 in 16.00'' Minimum 8 (max) 41611269' 371 8 907-283-1309Unit Phone: 0 Jane Grundin Maximum Report By:Logging Engineers: Depth Cly 416 C-3 20 Sd Silt TuffGvl 82.0 22 15 14 C-1 (current) Surface 24 24 24 hr Recap: Drill ahead F/11170' MD - T/11,233' MD and pump sweep. Drill ahead T/11300' MD and pump sweep. Called it TD . Wiper trip T/10491' MD, back reaming two stands on trip. Ran back to bottom, pump sweep, CBU. Back reaming out of hole at time of report. Mas Gas: 151 units Fluids: 0 downhole losses Geology: 50% Siltstone: gry- brnsh gry, frm, blky, fri, sd, mod ind; SHOW: n stn, n vis fluor, slw stmg bl wt ct, n res rng; 20% Sandstone: wh-lt gry, sft, f-c gr, sb rnd, mod srt, pr consol, tf Mtrx; 20% Shale: lt gry, lt brn, frm, blky, flky, ind; 10% Coal: blk, frm-hrd, blky, flky, ang, vit. . * (current) Surface 82.0 C-1Depth Cly C-3 Sd Silt TuffGvl 0 907-283-1309Unit Phone:Jane Grundin Maximum Report By:Logging Engineers: Minimum (max) Jake Hansen / Jane Grundin 63 in 16.00'' - C-2 9 5/8" 0.6638.5 24 hr Max 43 132 L-80 11300' 11300' 0' Max @ ft Current Time: - SPP (psi) MBT 11300' pH 0.663 Siltst X-56 Grade PDC 11300' 2RR1 Size Hours Set At Casing Summary Bit # 2 Depth ShClyst - Flow In (gpm) Flow In (spm) (ppb Eq) 249' TFA Yesterday's Depth: R/U to test BOPRig Activity: Current Depth: 24 Hour Progress: Date: AK-AM-0090150915 Lithology (%) Weight Job No.: Daily Charges: Total Charges: Jimmy Greco 1.02 Coal 50 Conductor Comments BTC Cement PV Depth in / out 3200' cP 19 3330' 4.0 130' Footage YP (lb/100ft2) 9.40 Condition 1-1-WT-A-X-I-NO-DTF Weld WOB 40.0 C-5n Gas Summary C-4i C-4n C-5i Chromatograph (ppm) Ss (current) Units* Mud Type Lst Type 3186' 80' 25 Average 21Background (max)Trip RPM ECD (ppg) ml/30min API FL 4 Avg 3.3 100% Gas In Air=10,000 UnitsConnection 8.3 8.5PDC 10.10 Size KCL 3330' Bit Type Saxon 169 Report For: Tools Gamma/Res -- Min ROP Avg Morning Report Report # 20 Customer: Well: Area: Location: Rig: Beaver Creek 24 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek ROP (ft/hr) 3.07 @ Mud Data to - Gallons/stroke - Depth MWD Summary 10-Oct-2014 12:00 AM Current Pump & Flow Data: 0 Max 95% mg/l 32500 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides 24 hr Recap: Back reamed T/6615' MD and began pulling on elevators. TOOH to surface. L/D BHA, R/U to test BOP at time of report. Mas Gas: N/A Fluids: 0 downhole losses Geology: N/A . * Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 32500 USED 11-Oct-2014 12:00 AM Current Pump & Flow Data: 887 Max 95% Depth MWD Summary ROP (ft/hr) 3.07 @ Mud Data to - Gallons/stroke - Morning Report Report # 21 Customer: Well: Area: Location: Rig: Beaver Creek 24 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek Saxon 169 Report For: Tools Gamma/Res -- Min ROP Avg 8.3 8.5PDC 10.10 Size KCL 11300' Bit Type 100% Gas In Air=10,000 UnitsConnection RPM ECD (ppg) ml/30min API FL 8 Avg 3.3 Background (max)Trip Average 8943 Mud Type Lst Type 3186' 80' 25 Ss (current) Units* Chromatograph (ppm) C-4i C-4n C-5i C-5n Gas Summary YP (lb/100ft2) 9.40 Condition 1-1-NO-A-X-2-NO-TD Weld WOB 40.0 PV Depth in / out 3330' cP 19 0' 4.0 7970' Footage Coal 85 Conductor Comments BTC Cement Lithology (%) Weight Job No.: Daily Charges: Total Charges: Jimmy Greco 241.24 Yesterday's Depth: TIH/ Clean Out RunRig Activity: Current Depth: 24 Hour Progress: Date: AK-AM-0090150915 Depth ShClyst - Flow In (gpm) Flow In (spm) (ppb Eq) 249' TFA 8.5 11300' 3RR1 Size Hours Set At Casing Summary Bit # 2RR1 MBT 11300' pH 0.663 Siltst X-56 Grade 11300' 11300' 0' Max @ ft Current Time: - SPP (psi) 24 hr Max 100 307 L-80 - C-2 9 5/8" 3.1428.52 Jake Hansen / Jane Grundin 63 in 16.00'' Minimum (max) 0 907-283-1309Unit Phone:Jane Grundin Maximum Report By:Logging Engineers: Depth Cly C-3 Sd Silt TuffGvl 82.0 C-1 (current) Surface 24 hr Recap: Completed testing of BOP, P/U clean out assembly, RIH T/shoe, serviced rig, RIH T/8778' MD. CBU 8,943U. RIH w/ tight spots at 8824' MD, 9867' MD, and 10070' MD. RIH, 9915' MD at time of report. Mas Gas: N/A Fluids: 0 downhole losses Geology: N/A . * Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 31000 USED 12-Oct-2014 12:00 AM Current Pump & Flow Data: 0 Max 95% Depth MWD Summary ROP (ft/hr) 3.07 @ Mud Data to - Gallons/stroke - Morning Report Report # 22 Customer: Well: Area: Location: Rig: Beaver Creek 24 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek Saxon 169 Report For: Tools Gamma/Res -- Min ROP Avg 9.8 8.5PDC 10.45 Size KCL 11300' Bit Type 100% Gas In Air=10,000 UnitsConnection RPM ECD (ppg) ml/30min API FL 8 Avg 4.1 Background (max)Trip Average 9648 Mud Type Lst Type 3186' 80' 23 Ss (current) Units* Chromatograph (ppm) C-4i C-4n C-5i C-5n Gas Summary YP (lb/100ft2) 8.60 Condition 1-1-NO-A-X-2-NO-TD Weld WOB 40.0 PV Depth in / out 3330' cP 14 0' 4.0 7970' Footage Coal 85 Conductor Comments BTC Cement Lithology (%) Weight Job No.: Daily Charges: Total Charges: Jimmy Greco 241.24 Yesterday's Depth: POOH Rig Activity: Current Depth: 24 Hour Progress: Date: AK-AM-0091663907 Depth ShClyst - Flow In (gpm) Flow In (spm) (ppb Eq) 249' TFA 8.5 11300' 3RR1 Size Hours Set At Casing Summary Bit # 2RR1 MBT 11300' pH 0.663 Siltst X-56 Grade 11300' 11300' 0' Max @ ft Current Time: - SPP (psi) 24 hr Max 0 0 L-80 - C-2 9 5/8" 3.1428.52 Jake Hansen / Jane Grundin 53 in 16.00'' Minimum (max) 0 907-283-1309Unit Phone:Jane Grundin Maximum Report By:Logging Engineers: Depth Cly C-3 Sd Silt TuffGvl 82.0 C-1 (current) Surface 24 hr Recap: RIH T/10132, CBU 9648U and continued to circulate. 15% increase in flow, shut in well. Weighted up mud to 10.3 ppg and circulated through choke. Well stabilized and ran to bottom, weighted up mud to 10.4 ppg. Pumped sweep and began POOH. POOH at time of report. Mas Gas: N/A Fluids: 0 downhole losses Geology: N/A . * (current) Surface 82.0 C-1Depth Cly C-3 Sd Silt TuffGvl 0 907-283-1309Unit Phone:Jane Grundin Maximum Report By:Logging Engineers: Minimum (max) Jake Hansen / Jane Grundin 56 in 16.00'' 5.50'' - C-2 9 5/8" 3.1428.52 24 hr Max 0 0 L-80 11300' 11300' 0' Max @ ft Current Time: - SPP (psi) MBT 11300' pH 0.663 Siltst X-56 Grade 8.5 11300' 3RR1 Size Hours Set At Casing Summary Bit # 2RR1 Depth ShClyst - Flow In (gpm) Flow In (spm) (ppb Eq) 249' 17.0 TFA Yesterday's Depth: Run 5.5" CasingRig Activity: Current Depth: 24 Hour Progress: Date: AK-AM-0090150915 Lithology (%) P-110 Weight Job No.: Daily Charges: Total Charges: Jimmy Greco 241.24 Coal 85 Conductor Comments BTC Cement PV Depth in / out 3330' cP 15 0' 4.0 7970' Footage YP (lb/100ft2) 8.40 Condition 1-1-NO-A-X-2-NO-TD Weld WOB 40.0 C-5n Gas Summary C-4i C-4n C-5i Chromatograph (ppm) Ss (current) Units* Mud Type Lst Production Type 3186' 80' 24 Average 63Background (max)Trip RPM ECD (ppg) ml/30min API FL 8 Avg 4.4 100% Gas In Air=10,000 UnitsConnection 9.6 8.5PDC 10.40 Size KCL 11300' Bit Type Saxon 169 Report For: Tools Gamma/Res -- Min ROP Avg Morning Report Report # 23 Customer: Well: Area: Location: Rig: Beaver Creek 24 Hillcorp Alaska, LLC Kenai Peninsula Beaver Creek ROP (ft/hr) 3.07 @ Mud Data to - Gallons/stroke - Depth MWD Summary 13-Oct-2014 12:00 AM Current Pump & Flow Data: 0 Max 95% mg/l 31500 USED Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides 24 hr Recap: Finished L/D DP and clean out assembly. Changed rams and tested with bag. R/U Weatherford and RIH w/5.5" casing. CBU @ 3156' MD 63U. RIH @ 4581' MD at time of report. Mas Gas: N/A Fluids: 0 downhole losses Geology: N/A
