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Home My WebLink About2018-11-01_318-487RECEIVEDSTATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION CONFEDENTENL APPLICATION FOR SUNDRY APPROVALS I)n nnr �c on NOV 0 1 2018 1. Type of R s U U andon LJ Plug Perforations ❑ Fracture Stimulate Repair Well El Operations shutdown LJ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhllll s Alaska Inc. Exploratory 0 Development ❑ 215-209 3. Address: Stratigraphic ❑ Service 6. API Number: ❑ P. O. Box 100360, Anchorage, Alaska 99510 50-103-20730-00 �ptj 7. If perforating: 8. Well Name and Number: VT What Regulation or Conservation Order governs well spacing in this po N/A Will planned perforations require a spacing exception? Yes ❑ No D Tinmiaq 2 9. Property Designation (Lease Number): 10. Field/Pool(s): AA 081807 Exploratory 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): 4235' 4235' 3514' 3514' 3514' Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 108' 108' Surface 2052' 9-5/8" 2077' 2077' Intermediate Production 4198' 7" 4225' 4225' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 3688'-3708' 3688'-3708' 3-1/2" L-80 3645' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): SSSV - None SSSV - N/A Packer - Baker Premier Packer Packer - 3612' MD/ 3612' TVD 12. Attachments: Proposal Summar Wellbore schematic 13. Well Class.after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory 0 Stratigraphic ❑ Development ❑ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 2/18/2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended 0 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Sandeep Pedam Contact Name: Sandeep Pedam Authorized Title: S ff Coniplations Engineer Contact Email: Sandeep.Pedarn(@conocophillips.com Contact Phone: ;907) 263-4724 Authorized Signature:Date: d 3 o 2� COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test❑ Mechanical Integrity Tes❑ Location Clearance ❑ Other: Post Initial Injection MIT Req' Yes ❑ No ❑ Spacing Exception Required, Yes ❑ No y Subsequent Form Required: APPROVED BY I pproved by: COMMISSIONER THE COMMISSION Date: �� kirt Frmm and Form 10-403 Revised zov Approved application y6"'9�a 1 1 \ XC date of approval. attachments in Duplicate I2 �"� 20�� U �Av' /�1��/,� �r�. %, �a11�11� TO THE ALASKA OIL AND GAS CONSERVATION COMMISSION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) Commission in the Matter of the ) AFFIDAVIT OF Garrett B. Haag Request of ConocoPhillips Alaska, Inc. for ) Hydraulic fracturing for the Tiomiaq 2 Well ) under the Provisions ) of 20 AAC 25.280 ) STATE OF ALASKA ) §§ THIRD JUDICIAL DISTRICT ) Garrett B. Haag, being first duly sworn, upon oath, deposes and states as follows: forth herein. My name is Garrett B. Haag. I am over 19 years old and have personal knowledge of the matters set I am Staff Landman for the well operator, ConocoPhillips Alaska, Inc. ("CPAI") Pursuant to 20 AAC 25.283 (1) CPA] prepared the attached Notice of Operations ("Notice"). On October 18, 2018, CPAI sent a copy of the Notice by certified mail to the last known address of all other owners, landowners, surface owners, and operators of record within a one-half mile radius of the current proposed well trajectory. Subscribed and sworn to this 18th day of October 2018. AJ t3 STATE OF ALASKA Garrett B. Haag ) THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this 18th day ofOctober2018, by Garrett B. Haag. Notary Public, State of Alaska My Commission Expires: eeemc�e EREBECCA OF ALASKA RY PUBLIC SINENSEN ifto� Expires At Con®coPh i I f i ps P. O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Alaska Garrett B. Haag, Staff Landman Land Department, ATO 1480 Phone (907) 265-6297 Fax (907) 263-4966 Garrett.B.Haag@cop.com October 18, 2018 VIA CERTIFIED MAIL To: Operator and Owners (shown on Exhibit 2) Re: Notice of Operations pursuant to 20 AAC 25.283 (1) for TiDmiaq 2 BLM Serial No. AA -081807, AA -081809 Bear Tooth Unit, Alaska CPAI Contract No. 206223 CPAI Lease No. 932542 Dear Operator and Owners: ConocoPhillips Alaska, Inc. ("CPAI") as Operator and on behalf of the Bear Tooth Unit, hereby notifies you that it intends to submit an Application for Sundry Approvals for stimulation by hydraulic fracturing pursuant to the provisions of 20 AAC 25.280 ("Application") for the TiDmiaq 2 Well (the "Well"). The Application will be fled with the Alaska Oil and Gas Conservation Commission on or about October 19, 2018. This Notice is being provided pursuant to subsection of 20 AAC 25.283. The Well has been drilled as a straight hole on lease AA -081807 as depicted on Exhibit 1 and has the locations as follows: Location FNL FEL Township Range Section Meridian Surface 1,161' 2,925' l ON 1 W 34 Umiat Bottomhole 1,163' 2,903' ION 1 W 34 Umiat Exhibit 1 shows the location of the Well and the lands that are within a one-half mile radius of the Well, including the reservoir section ("Notification Area"). Exhibit 2 is a list of the names and addresses of all owners, landowners and operators of record of all properties within the Notification Area. Upon your request, CPAI will provide a complete copy of the Application. If you require any additional information, please contact the undersigned. Sincerely, AW4 B -A Garrett B. Haag Staff Landman Attachments: Exhibits 1 & 2 Notice of Operations pursuant to 20 AAC 25.283 (1) for Tirrniaq 2 October 18, 2018 Exhibit 1 Page 1 of 1 Notice of Operations pursuant to 20 AAC 25.283 (1) for TiDmiaq 2 October 18, 2018 Exhibit 2 List of the names and addresses of all owners, landowners and operators of all properties within the Notification Area. Operator and Record Title Owner of Oil and Gas Leases: ConocoPhillips Alaska, Inc. 700 G Street, Suite ATO 2176 (Zip 99501) P.O. Box 100360 Anchorage, AK 99510-0360 Attention: Lorna Richmond, Alaska Exploration Manager Landowner: United States Department of Interior Bureau of Land Management Alaska State Office 222 West 7th Avenue, #13 Anchorage, Alaska 99513 Attn: Branch Chief, Energy and Minerals Surface Owner: United States Department of Interior Bureau of Land Management Alaska State Office 222 West 7th Avenue, #13 Anchorage, Alaska 99513 Attn: Branch Chief, Energy and Minerals Via Certified Mail No. 7017 0530 0000 3354 9786 Via Certified Mail No. 7017 0530 0000 3354 9786 Page 1 of 1 Section 1 - Affidavit 10 AAC 25,283 ra), ) Exhibit 1 is an affidavit stating that the owners, landowners, surface owners and operators within one- half mile radius of the current or proposed wellbore trajectory have been provided notice of operations in compliance with 20 AAC 25.283(a)(1) Affidavit Section 2 - Plat 20 AAC 25.2$2 (a)(2) Plat 1: Wells within 0.5 mile Table 1: Wells within 0.5 mile Sec -',Jon 3 - F.r eshwater Aquifers 20 AAC 25.283(a)(3) There are no freshwater aquifers or underground sources of drinking water within one-half mile radius of the current or proposed wellbore trajectory. See shallow formation water salinity evaluation next page. Section 4 - flan for Baseline Water Sampling for Water Wells 20 AAC 25.283 (a) (4) There are no water wells located within one-half mile of the current or proposed wellbore trajectory and fracturing interval. g? 8, 0 4- +j 0 >- aj Z .? 4-J Q w (U VI m txo to ro CA 41 4E QJ_ co ci 7" 0 0 4� b 0 Co Qj CL v tB > ........................................... Section S - Detailed Cernentling and casing inf®rma i®n 20 AAC 2S.283(a)(S) All casing is cemented in accordance with 20 AAC 25.030(b) and tested in accordance with 20 AAC 25.030 (e) when completed. See Wellbore schematic for casing details. Section 6 - Assessment of each casing and cementing operation to be performed to construct or repair the well 20 AAC] 25.283(a)(6) Casing & Cement Assessments: The 9-5/8" casing cement pump report on 11/16/2014 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 11 ppg Arctic Lite Crete cement and 15.8 ppg class G tail cement. The plug bumped at 400 psi and the floats were checked and they held, The 7" casing cement pump report on 2/28/2016 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8 ppg class G cement. The plug bumped and the floats were checked and held. Full returns and reciprocated casing throughout the cement job. A CBL/VDL (cement bond log) was run on 2/29/2016. The log shows strong indication of good coupling between casing -cement -formation in the form of VDL formation arrivals. A TOC can be seen at 2810' MDRT. All casing is cemented in accordance with 20 AAC 25.030 and each hydrocarbon zone penetrated by the well is isolated. Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successful fractured within design limits. Section 7 - r essure test informal -ion and plans to pressure -gest easing and tubings installed in the well 2C AAC 25.233 Ca)r7) 20 AAC 23.253. Hydraulic fracturing On 02/17/2016 the 9-5/8" casing was tested on rig to 3000 psi, On 02/29/2016 the 7" casing was pressure tested to 3000 psi, The 7" x 3-1/2" annulus will be pressure tested to 2,750 psi prior to (racing The 3-1/2" tubing will be pressure tested to 4,025 psi prior to fracing. Table 1: Required Pressures A GCC Requirsd PI-eSSUrGS jail in psi] Maximum Predicted Treating Pressure (MPTP) 4,700 Annulus pressure during frac 2,500 Annulus PRV setpoint during frac 2,600 Annulus pressure test 2,750 Tubing pressure Test 4,025 Nitrogen PRV 5,700 Highest pump trip 5,200 Section 8 - Pressure ratings and schematics for the Wellbore, Wellhead, POPE and Treating head 20 AAC 25.283(a)(8) 20 AAC 25.283. Hydrauft fracturing (a) Before hydraulic fracturing, the operator must submit an Application for Sundry Approvals (Form 10- 403) under 20 AAC 25,280, Unless modified or altered by pool rules established under 20 AAC 25.520, the application must include (8) accurate pressure ratings and schematics for the wellbore, wellhead, BOPE, and treating head; Size Weight Grade API Burst API Collapse 9 & 5/8" 40.0 L-80 5,750 psi 3,090 psi 7 26.0 L-80 7,240 psi 5,410 psi 3 & %" 9.3 L-80 10,159 psi 10,533 psi cable 2: Pressure Ratings S -irnula lion Surface Rig -Up press. Rating on all surface treating lines 10,000 psi Main treating line PRV set to 95% of max. treating pressure IA parallel PRV set to 2600 psi Frac pump trip pressure setting staggered and set below main treating line PRV Tree saver used on all fracs rated for 15,000 psi f'u11 "fru :fr, Tree Saver With We'lihead m p OIL STATES Energy Services (Canada) Im QUOTE4: Maximum Allowable PFumping Rates PROPOSAL -- OASKO VOUTION Pressure rating: 15,000psi 3 Vgoomilhead C-rechnoliogies wo p;*1 a.16-SDOY., M Wl N GENERA,r[ON 5 WELLHEAD !pm In v, fcrjw,uE h . -�6.3 il , fft i T Kn jJ_,lq4 C:Iwll,-,v I -ILL fffs-SOU IlilKi., NAK EXPLORNELLNAME TINMIAQ2 WELLBORE TINMIAO 2 LL ƒ / ® \ \ a) \\ R ® i\7\ $o 2 122/ f\ 2 /ƒ§b� § /§ e 2 n o Co2 t O. E 777& / k\E §�) \ACLCL 0- o Eo ==K ¥I b E/x o§ �4 \ \7� /Q\ 0\� ® y k E \ C _ § c CL 6 � = \ / , / f \ . , . \ / / ƒ ° \ . f / 3 E % _- _ © t 2 I , . « _ 04 0ce \ 0 LO' ` LO \ k \c) f > -7 \ / \ o n . cc @ E LL co C\l LL A / Q A / , f =` ' ' 2 / / \ C) \ \ \ > E \ k 7 a)c m b \ § \ k 00 } LL % \ Wellbore schematic 16" 62.54 M40 Conductor 106'MD/TVD Conductor Cemented to Surface 12 ',.Hole Surface Cement Base PemaFrost -832' MD 1TVD Lead- 11.0 PPG Arctic L1teCRETE Lom Surface to -1500' .. .. " Tat! -15,8 PPG'G' from 1500' to 207T Producthn Cement Tall -15.8 PPG'G' from 2851' to 4240' Completion 9 518` 40# L80 Hydril 563 Surface Casing 3 W tubinp to surface x. 3 %' z 2060' MD / TVD 'alidi,ut sleeve across Falwn?nterval cross r lco K-3fiop Nanushuk-2335 MD1TYD. . F Pie installed plug is lowest nipple profile .. 81f2° HOIe Gas Left Mandrel (KSMG) - 3100' D Nippte:-3150' Pat;,on Sand Top- 8294' MD l WD HaNbLilen Feed -Through Packer- 3250' SLB CuarL> Duz1-Read Gauge - 3300' Perts Planned M Falcon i3�- ^} 7-_ X Nipple - 3350' Sliciing Sleeve - 3430' WalibuMon Feed-Thmugh Packer - 3530' VR low Sand Top XN Nipple -3560' -3867'MDITVD 'f SLE. uare gauge -3650' Perls @ 3666'-370V TD-4,"25'MD/TVD 7"26# LV HyJi 563 Pmdac9on Casing F ro,10' 0- 3 035l 7"26# TN710 h1yd-'s'. 563 ProductBOn Casing Frc;ni 3035' - 4225' Section 9 - Data for Fracturing zone and confining zones 29 AAC 25.231a)(9) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that: The fracturing zone consists of the Cretaceous Brookian "Falcon" Topset sands. The Falcon interval is approximately 70' ft TVT with the top of the Falcon interval at 3247 ft TVDSS (3337 ft MD) based on the Tigmiaq 2 well logs. The Falcon interval is comprised of very fine to medium grained sandstone interbedded with mudstone, siltstone and localized cemented zones. The estimated fracture pressure for the Falcon sand is 12.7 ppg. The overlying confining zone has an overall thickness of 44' ft TVT and consists of Cretaceous Brookian Nanushuk Topset mudstones. The top of the confining zone was denoted by resistivity marker at 3203 ft TVDSS (3293 ft MD) in the Tigmiaq 2 well. The estimated fracture pressure for the overlying confining layer is at least 16.0 ppg. The underlying confining zone consists of Cretaceous Brookian Nanushuk Topset mudstones and is greater than 97 ft TVT. The estimated fracture pressure for this zone is at least 16.0 ppg. Section 10 - Location, Orientation and a Report on Mechanical Condition of Each Well teat may Transect Confining Zone 20 AAC 2S.283'�a)(10) There are no wells within on -half mile radius of the proposed wellbore trajectory Section 11 - vocation of, Orientation of and Geological Data for Faults and Fractures that may Transect the Confining Zones 20 AAC 2S.283(a)(11) CPAI has formed the opinion based on seismic, well and other subsurface information available that there are 0 (zero) faults that transect the Willow interval and enter the confining zone within one-half mile radius of the Tiomiaq 2 wellbore trajectory. The effective fracture half-length is estimated to the 500 ft. If there are indications that a fracture has intersected a fault during fracture operations, CPAI will go to flush and terminate the stage immediately. bmf d t Well i_Oa360TI C372 1121f mile ta+&s =TDImsh�p Flange Plat 2: T-6 Fault Analysis TEq iaq 2 Fault Analysis Flat V11 — F "Is'00C a 9,L�U.03 9,72 9:2= ..._.. 0�4 Mile: Section 12 - Proposed Hydraulic Fracturing program 20 AAC 25.283(a)('L2) Tinmiaq 2 was drilled in Feb 2016 as an appraisal well in the Willow and Falcon formations. The well is completed with 3-1/2" tubing. The Willow sand formation was perforated post rig and tested in 2016. In 2019, the well will be worked over with a rig, 3-1/2" tubing will be run with a DHG, selective and packer to test the Falcon sands. The Falcon sands will be perforated on rig (planned perf depth 3345'-3385'MD) and stimulated. Proposed Procedure: Halliburton Pumping Services: (Falcon Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre -frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 1,000' TVD. 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. Ensure the BLM Sundry has been reviewed and approved by the BLM. 5. MIRU 2 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 1002 F seawater (approx. 500 bbls are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 6. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 7. MIRU NES Frac Equipment. 8. PT Surface lines to 8,000 psi using a Pressure test fluid. 9. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 10. Pump the Frac job by following schedule with a maximum expected treating pressure of 4,700 psi. Sectioni 13 - Post-Fracture Wehbal e Ueecanup mad Fiuki RecDver r la 20 AIC 25.2B3 Little Red Services with be the Well Testing company for Tinmiaq 2. The base case for the flow test consists of four periods: The "post -frac high draw down clean up flow" period is intended to produce the frac fluid back as quickly as possible until the well is producing at less than 10% water cut. We will likely need N2 to kick the well off and will have it on location to sustain flow if needed. The "shut-in pressure build up period" will be equal to the time of the first flow. The "main flow period" will impose minimal drawdown while maintaining stable flow for the duration. We will collect pressurized gas and oil samples, and stock tank oil. We will flare the produced gas through testing vendor's flare stack with a continuous pilot. During the "main shut-in period" we will monitor the pressure buildup. There will be a tank farm on location with 7,400 BBL capacity. Fluid will be trucked to either Alpine or Kuparuk (depending on what fluid) with appropriate North Slope Manifests and volumes for each transport. We will take tank straps before and after transport loading to calculate total fluid leaving location. During the testing operations, we will be taking 30 min tank straps to confirm volumes. Shakeouts will be taken on 30 min intervals for water cut and BS&W. A Micromotion and Phase Dynamics will also be installed for continuous flow rate monitoring. Once the flow test is complete we will suspend the well with permanent downhole gauge for pressure monitoring. Period Duration (Hrs) 1 Post Frac High Drawdown Clean Up Flow 36 2 Shut In Pressure Build Up Period 36 3 Main Flow Low Drawdown Perios 168 4 Main Shut In Period 350+ The "post -frac high draw down clean up flow" period is intended to produce the frac fluid back as quickly as possible until the well is producing at less than 10% water cut. We will likely need N2 to kick the well off and will have it on location to sustain flow if needed. The "shut-in pressure build up period" will be equal to the time of the first flow. The "main flow period" will impose minimal drawdown while maintaining stable flow for the duration. We will collect pressurized gas and oil samples, and stock tank oil. We will flare the produced gas through testing vendor's flare stack with a continuous pilot. During the "main shut-in period" we will monitor the pressure buildup. There will be a tank farm on location with 7,400 BBL capacity. Fluid will be trucked to either Alpine or Kuparuk (depending on what fluid) with appropriate North Slope Manifests and volumes for each transport. We will take tank straps before and after transport loading to calculate total fluid leaving location. During the testing operations, we will be taking 30 min tank straps to confirm volumes. Shakeouts will be taken on 30 min intervals for water cut and BS&W. A Micromotion and Phase Dynamics will also be installed for continuous flow rate monitoring. Once the flow test is complete we will suspend the well with permanent downhole gauge for pressure monitoring. 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Q) cn C: (3) GJ O U O O S 4-J �— Z O Q,E a�Ln E L', 3 o. o E 13 / / ......... . . ...... { �§ ii CL )� �k))\6 \ ; �/ 2\ ■ / / ......... . . ...... { �§ g Z O y m a 0 0 000 0 0 0 000°0 0 0 0 0 0 3 0a o 0 0 o N 0 v 0 0 o 0 0 0 0 0 o 0 0 0 0 — 5 �o 0 o 0 0 t a O O 0p 0 0 0 0 0 0 0 0 0 0 0 0 0 O 00 a a � u e o . 0 0 o a o ❑ a 0 0 0 0 0 0 o g o 0 0 0 2 E E -� a v"i r o 0 0 0 o S 0 0 ❑ 7 E L m � ❑ N N P T T n O O Obi O N N N � w u E Q` N N 01 rtl b N r T OI � � �y Off eNrl N C W ❑ V E '� O O OO O O O O N ❑ pOj m 0 0 O O 4 1 O S 0 0 ni V 0 0 Vr �C � v ❑v a 0 0 a o 0 0 ❑ 0 0 ❑ N O N N N N N O O N O i� b m� � Z T O N b I� m Qt O N rtl ti b E 2 d. 80-0 N7 uoop j Llen�alu� c •N cu Wallace, Chris D (DOA) From: Pedam, Sandeep <Sandeep.Pedam@conocophillips.com> Sent: Friday, December 14, 2018 11:48 AM To: Wallace, Chris D (DOA) Cc: Davies, Stephen F (DOA); Boyer, David L (DOA); Wilson, Gregory C; Mlacnik, Martin Subject: Re: [EXTERNAL]Tinmiaq 2 PTD 2152090 Sundry For Frac 318-487 confidentiality clarification Chris, Thanks for your email. We can confirm that there is nothing confidential in the application. We appreciate you checking with us. Regards, Sandeep Get Outlook for Android From: Wallace, Chris D (DOA) Sent: Tuesday, December 11, 10:33 AM Subject: [EXTERNAL]Tinmiaq 2 PTD 2152090 Sundry For Frac 318-487 confidentiality clarification To: Pedam, Sandeep Cc: Davies, Stephen F (DOA), Boyer, David L (DOA) Sandeep, We have received the Sundry Application for Tinmiak Falcon Hydraulic Fracture Stimulation that is marked by CPAI as confidential. Our records show confidentiality expired 5/11/2098. Please confirm that there is or isn't anything confidential in the application. If there is I will need a redacted copy for posting to our website. If there is in fact no confidential data in the application, I can cross off the confidentiality on the application and post to our website ASAP to progress this along. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace(d)-alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace(aDalaska.gov.