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HomeMy WebLinkAbout2025_12_02_325-7321. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name:4. Current Well Class:5. Permit to Drill Number: 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? KRU 3T-731B Yes No 9. Property Designation (Lease Number): 10. Field: Coyote Oil Pool 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD:Junk (MD): 13118 4181.00 13116 4181.00 1972 None None Casing Collapse Structural Conductor Surface 2470 Intermediate 4790 Intermediate 7850 Liner 9210 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:Rodrigo Ruysschaert Rodrigo Ruysschaert Contact Email:Rodrigo.Ruysschaert@cop.com Contact Phone: 907-621-0671 Authorized Title:Completions Engineer 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 Authorized Name and Digital Signature with Date:Dec 01 2025 AOGCC USE ONLY Suspension Expiration Date: Subsequent Form Required: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Perforation Depth MD (ft):Perforation Depth TVD (ft):Tubing Size:Tubing Grade:Tubing MD (ft): 4-1/2"L-80 4926.98 Halliburton TNT Prod Packer Baker SLZXP, No SSSV TNT packer: 4786 ft MD/4076 ft TVD SLZXP packer: 4922 ft MD/4103 ft TVD Dec 10 2025 989 7-5/8"5087.0 4127.00 10860 8194.13 4-1/2"13116.0 4181.00 11590 2585.1 10-3/4"2625.0 2511.00 5210 4060.1 7-5/8"4098.0 3776.00 6890 80 20"119.0 119.0 PRESENT WELL CONDITION SUMMARY MPSP (psi):Plugs (MD): Length Size MD TVD Burst ADL025528 / ADL025544 Kuparuk Field STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ConocoPhillips Alaska Inc.225-124 P.O. Box 100360, Anchorage, Alaska 99510-0360 50-103-20905-02-00 Will perfs require a spacing exception due to property boundaries? Current Pools:Proposed Pools: m n s _ t c N 2 66 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-732 December 2, 2025 VIA E-MAIL To: Operator and Owners (shown on Exhibit 2) Re: Notice of Operations for 3T-731B Well ADL 025528 & ADL 025544 Kuparuk River Unit, Alaska CPAI Contract No. 203828 Pursuant to 20 AAC 25.283, ConocoPhillips Alaska, Inc. (“CPAI”) as Operator of the Kuparuk River Unit, hereby notifies you that it intends to submit an Application for Sundry Approvals for stimulation by hydraulic fracturing in accordance with 20 AAC 25.280 (“Application”) for the 3T- 731B Well (the “Well”). The Application will be filed with the Alaska Oil and Gas Conservation Commission on or about December 2, 2025. The Well is currently planned to be drilled as a directional horizontal well on lease ADL 025528 and ADL 025544 as depicted on Exhibit 1, and has locations as follows: Location FNL FEL Township Range Section Meridian Surface 3,636’ 5,147’ T12N R7E 1 Umiat Top Open Interval 4,360’ 4,395’ T12N R7E 1 Umiat Bottomhole 1,790’3,313’ T12N R7E 13 Umiat Exhibit 1 shows the location of the Well and the lands that are within a one-half mile radius of the current proposed trajectory of the Well (“Notification Area”), which includes the reservoir section. Exhibit 2 is a list of the names and addresses of all owners, landowners, surface owners, and operators of record at the time of this Application for 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, Ryan C. King, CPL Staff Land Negotiator Attachments: Exhibits 1 & 2 Ryan C. King, CPL Staff Land Negotiator Land & Business Development P.O. Box 100630 Anchorage, AK 99510-0360 Office: 907-265-6106 Fax: 907-263-4966 ryan.c.king@cop.com Sincerely, Ryan C. King, CPL BCC: Rodrigo Ruysschaert David Lee Jason Parker John Evans Patrick Perfetta Exhibit 1 Exhibit 2 List of the names and addresses of all owners, landowners, surface owners, and operators of record of all properties within the Notification Area. Operator & Owner: ConocoPhillips Alaska, Inc. 700 G Street, Suite ATO-1480 (Zip 99501) P.O. Box 100360 Anchorage, AK 99510-0360 Attn: GKA Asset Development Manager Owner (Non-Operator): ConocoPhillips Alaska, Inc. II ExxonMobil Alaska Production Inc. 700 G Street, Suite ATO 1226 PO Box 196601 Anchorage, Alaska 99510 Anchorage, AK 99519 Attn: GKA Asset Development Manager Attn: Todd Griffith Landowners: State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 1100 Anchorage, AK 99501 Attention: Derek Nottingham, Director Surface Owner: State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 1100 Anchorage, AK 99501 Attention: Derek Nottingham, Director Section 1 - Affidavit 10 AAC 25.283 (a)(1) 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). Section 2 – Plat 20 AAC 25.283 (2)(A) Plat 1: Wells within 1/2 mile Table 1: Wells within 1/2 miles (2)(C) SECTION 3 – FRESHWATER AQUIFERS 20 AAC 25.283(a)(3) There are no known underground sources of drinking water within a one-half mile radius of the current or proposed wellbore trajectory. See Conclusion number 5 of the Area Injection Order AIO 45- Coyote Oil Pool, which states “An aquifer exemption is not necessary for this project because the total dissolve solids of the water in the COP is over 21,000 mg/l, and the KRU has a valid aquifer exemption from the US EPA under 40 CFR 147.102(b)(3).” SECTION 4 – PLAN 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. A water well sampling plan is not applicable. SECTION 5 – DETAILED CEMENTING AND CASING INFORMATION 20 AAC 25.283(a)(5) All casing is cemented and tested in accordance with 20 AAC 25.030. 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 10-3/4” casing cement pump report on 3/15/2025 shows that the original job pumped as designed. The cement job was pumped with 438 barrels of 11.0 ppg lead cement and 58 barrels 15.8 ppg tail cement, displaced with 9.8 ppg mud. The plug bumped at 950 psi and the floats held. 150 bbls of cement returned to surface. The 7-5/8” casing cement report on 11/20/2025 shows that the job was pumped with 50 BBLS 15.3 ppg Tail Cement. The cement was displaced with 216.2 BBLS 10.0 ppg NAF via rig pumps at 6 BPM. Reduce to 3 BPM for last 12 BBL. Plugs bumped at 2146 stks with 866 psi. (95% efficiency), pressure up to 1380 psi and hold for 5 min. Bleed off pressure, and check floats - floats held. Cement in place @ 0300 hrs on11/20/2025. A sonic log indicated the cement top at 3,733’ MD / 3,512’ TVD (1270’ MD / 606’ TVD above the Coyote). The 4-1/2" production liner was cemented on 11/28/2025, the job was pumped with 68 BBLS 10.5 PPG Mud Push spacer, 254 BBLS 15.3 ppg Tail Cement, displaced with 154.8 BBLS of 9.5 PPG CI Brine via rig pumps at 3-1 BPM (adjusted based on losses). Increase rate to 3 BPM for last 6.8 BBL. Plug bumped with 1130 psi, pressured up to 1930 psi and held for 5 min. Bled off pressure & floats checked good. Cement in place @ 13:00 HRS on11/28/2025. Lost 42 BBLS based on pumping 254 BBLS with a gauge hole volume of 172 BBLS & 40 BBLS of cement circulated to surface. Summary All casing is cemented in accordance with 20 AAC 25.030 and each hydrocarbon zone penetrated by the well is isolated. SECTION 7 – PRESSURE TEST INFORMATION AND PLANS TO PRESSURE-TEST CASINGS AND TUBINGS INSTALLED IN THE WELL 20 AAC 25.283(a)(7) On 3/17/2025 the 10-3/4” casing was pressure tested to 3,000 psi for 30 minutes On 11/20/2025 the 7-5/8” casing was pressure tested to 3,950 psi for 30 minutes. On 11/30/2025 the 4-1/2” tubing was pressure tested to 4,400 psi for 30 minutes prior to rig down. On 11/30/2025 the 7-5/8” casing by 4-1/2” tubing annulus was pressure tested to 3,850 psi for 30 minutes prior to rig down. The 4-1/2” tubing will be pressure tested to 4,200 psi for 30 minutes and the 7-5/8” casing by 4-1/2” tubing annulus will be pressure tested to 3,850 psi for 30 minutes post-rig. AOGCC Required Pressures [all in psi] Maximum Predicted Treating Pressure (MPTP) 7,075 Annulus pressure during frac 3,500 Annulus PRV setpoint during frac 3,600 7-5/8" Annulus pressure test 3,850 4-1/2" Tubing pressure Test 4,075 Electronic PRV 8,075 Highest pump trip 7,575 SECTION 8 – PRESSURE RATINGS AND SCHEMATICS FOR THE WELLBORE, WELLHEAD, BOPE AND TREATING HEAD 20 AAC 25.283(a)(8) Size Weight, ppf Grade API Burst, psi API Collapse, psi 10-3/4” 45.5 L-80 5,209 2,474 7-5/8” 29.7 L-80 6,885 4,789 7-5/8” 33.7 P-110S 10,860 7,870 4-1/2” 12.6 P-110S 11,590 9,210 4-1/2” 12.6 L-80 8,430 7,500 Table 2: Wellbore pressure ratings Stimulation Surface Rig-Up Kuparuk 10K Frac Tree SECTION 9 – DATA FOR FRACTURING ZONE AND CONFINING ZONES 20 AAC 25.283(a)(9) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that: The fracturing zone, the gross Coyote interval, has an average thickness greater than 150 ft TVD over the course of the lateral section of well 3T-731B, from where it intersects the top formation at 5,003’ MD to TD of the well. At the heel of the well it has a gross thickness of ~100’ thickening to ~215’ at the toe of the well. The Coyote interval is comprised of thinly interbedded sandstone and siltstone layers. The sandstone and siltstone components are litharenites, moderately to well sorted, and are of the size range from silt to very fine sand. The estimated fracture pressure for the Coyote interval is approximately 12.9-16.1 ppg based on FIT/LOT data. The overlying confining interval is represented by distal toe of slope (deep marine) claystone with thin siltstone beds of the Cretaceous Seabee Formation. This interval is present in thicknesses of ~250’ TVD in the vicinity of the 3T-731B wellbore. The top of the confining intervals starts at ~3,752’ TVDSS (4,135’ MD). It should be noted that slope to basin shales and siltstones are present from the top of the Seabee formation to the surface casing shoe at ~2,625’ MD. This interval acts as a continuation of the upper confining interval. CPAI estimates the fracture closure pressure gradient of the section above the Coyote to range from 0.67 to 0.73 psi/ft based on diagnostic fracture injection testing (DFIT) in the 3S-24B well and recent data collection in the 3S-719 and 3S-721 wells. The data collection in the 3S-719 and 3S-721 wells included LOT’s to better understand the fracture gradient of the overlying Seabee formation. Based on this testing the leak off point (LOP) of the overlying Seabee ranges from 0.73 to 0.78 psi/ft, and the fracture breakdown pressure (FBP) ranges from 0.82 – 0.93 psi/ft. Based on our dynamic fracture modeling, the fracture could propagate into the overlying interval, which was observed in the 3S-24B vertical well. The log results from the 3S-24B showed 34’ of potential fracture growth into the overburden compared to the ~250’ of TVT of the overlying zone. Additionally, geomechanical testing completed on the overburden core proved there is no remaining conductivity within a fracture that propagates into the overlying zone due to proppant embedment and interaction of the frac fluid with the rock. Post-frac injection will be at or below the fracture closure pressure (Pc) of the overlying seal which is less than the fracture propagation pressure (FPP). The lower confining interval of the Coyote comprises slope to basin floor mudstones of the Torok formation, which are present in thicknesses of ~830’ TVD in the vicinity of the 3T-731B wellbore. This same confining zone forms the upper confining interval of the Kuparuk River Unit, Torok Oil Pool. The estimated fracture gradient for this section ranges from 15-18 ppg. The base of the gross Coyote interval is estimated from seismic to be at ~4,163 ft TVDSS at the heel, and ~4,250’ ft TVDSS at the toe of the well. The estimated formation pressure within the Coyote interval is 1695 – 1,817 psi at a depth of 4,100’ TVDSS. SECTION 10 – LOCATION, ORIENTATION AND A REPORT ON MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT CONFINING ZONE 20 AAC 25.283(a)(10) ConocoPhillips has formed the opinion, based on following assessments for each well and seismic, well, and other subsurface information currently available that none of these wells will interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory. Casing & Cement assessments for all wells that transect the confining zone: 3S-17 & 3S-17A: ConocoPhillips Alaska, Inc. performed Plug and Abandonment operations on 3S-17 and 3S- 17A (sidetrack from 3S-17 on 4/29/2003), commencing operations on 7/30/2022 and completing the Plug and Abandonment on 9/25/2023. A cement retainer was set at 8,333’ MD via coil tubing and 27 bbls of cement was pumped below the retainer and 2 bbls on top of the retainer. Cement was tagged at 8,324’ SLMD and a passing MIT-T and MIT-IA was performed and witnessed by AOGCC on 8/13/2022. The tubing was then cut at 8,273’ MD and the tubing pulled out of hole. A bridge plug was set at 5,883’ MD in the 7” casing and the 7” casing was perforated from 5,707’-5,857’ MD. Coil was utilized to perf wash and cement with 68bbls of 15.8ppg cement pumped into the perforations. TOC was tagged at 5,513’ SLMD in the 7” casing and a MIT-T performed to 1500 psi, witnessed by AOGCC (pg. 16 at link below). TOC was determined in the annulus at 5,707’ MD / 4,022’ TVD / 3,965’ TVDSS via log. Coil was used to pump 22 bbls of 15.8ppg cement in the 7” casing. The TOC was tagged at 5,273’ MD and a MIT-T performed to 1,500 psi, witnessed by AOGCC (pg. 15 at the link below). The top cement job was performed on 9/5/2023 with 223 bbls of 15.8ppg Class G cement and the 7” casing was cemented to surface. The final abandonment was completed on 9/25/23, witnessed by AOGCC (pg 2 at link below). 203-080 - Laserfiche WebLink 3S-19: ConocoPhillips Alaska, Inc. performed Plug and Abandonment operations on 3S-19, commencing operations on 1/1/2024 and completing the Plug and Abandonment on 3/25/2025. From the original cement job, a CBL was conducted on 12/22/2012 from 9170ft to surface. CBL log indicated good to fair cement from 9170ft to 7350ftMD. A cement retainer was set at 9,620’ MD via coil tubing and 35 bbls of cement was pumped below the retainer. Another cement retainer was set at 8,515’ MD and 50 bbls of cement was pumped below the retainer and 2 bbls on top. Cement was tagged at 8,274’ SLMD and a passing MIT-T was performed and witnessed by AOGCC on 5/17/2023 (pg. 15 at link below). The tubing was then cut at 8,271’ MD and the tubing pulled out of hole. A CIBP was set at 6,596’ MD in the 7” casing and the 7” casing was perforated from 6,420’- 6,570’ MD. Coil was utilized to perf wash and cement with 65bbls of 15.8ppg cement pumped into the perforations. TOC was tagged at 6,120’ SLMD in the 7” casing. TOC was determined in the annulus at 6,420’ MD / 4,033’ TVD / 3,977’ TVDSS via log. A CIBP was set at 6,598’ MD and coil was used to pump 42 bbls of 15.8ppg cement in the 7” casing. The TOC was tagged at 5,474’ MD and a MIT-T performed to 1,710 psi, witnessed by AOGCC (pg. 8 at the link below). A top cement job was performed on 12/30/2023 with 210 bbls of 15.8ppg Class G cement and the 7” casing was cemented to surface. Pressure was still observed at surface on the production casing. Cement was milled down to 3,780’ MD and a CIBP set at 3,777’ MD. The casing was tested against the CIBP to 1,650 psi, witnessed by AOGCC on 3/15/2025 (pg. 1 at the link below). An additional top cement job was completed on 3/16/2025 with 165 bbls of 15.8ppg cement from 3,777’ MD to surface. Awaiting final abandonment operations once the rig moves. 203-096 - Laserfiche WebLink 3S-22: ConocoPhillips Alaska, Inc. performed Plug and Abandonment operations on 3S-22, commencing operations on 5/1/2023 and completing the Plug and Abandonment on 3/25/24. Original drilling did not cover the zone of interest. A CBL was run prior to the P&A showing the original cement height at 6255' MD. A cement retainer was set at 7,690’ MD via coil tubing and 32 bbls of 15.8ppg cement was pumped below the retainer and 2 bbls on top of the retainer. Cement was tagged at 7,418’ SLMD and a passing MIT-T and MIT-IA was performed and witnessed by AOGCC on 5/12/2023 (pg. 12 at link below). The tubing was then cut at 7,420’ MD and the tubing pulled out of hole. A CIBP was set at 5,467’ MD in the 7” casing and the 7” casing was perforated from 5,291’-5,441’ MD. Coil was utilized to perf wash and cement with 68bbls of 15.8ppg cement pumped into the perforations. TOC was tagged at 5,107’ SLMD in the 7” casing and TOC was determined in the annulus at 5,291’ MD / 4,018’ TVD / 3,960’ TVDSS via log. Coil was used to pump 38 bbls of 15.8ppg cement in the 7” casing. The TOC was tagged at 4,445’ MD and a MIT-T performed to 1,500 psi, witnessed by AOGCC (pg. 5 at the link below). The top cement job was performed on 2/28/2024 with 193 bbls of 15.8ppg Class G cement and the 7” casing was cemented to surface. The final abandonment was completed on 3/25/24, witnessed by AOGCC (pg. 2 at link below). 203-011 - Laserfiche WebLink 3S-610: The 7-5/8” casing cement report on 3/23/2024 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 201 barrels of 15.3 ppg with BM-II (Bridge Maker II), followed with 22 barrels of 15.3 ppg without BMII. The plug did not bump, pressure held at 1140 psi indicating that floats are competent. A cement bond log indicates competent cement with a cement top @ 3,549 MD (3,156’ TVD / 3,092’ TVDSS). 223-126 - Laserfiche WebLink 3S-611: The 7-5/8” casing cement report on 10/13/2018 shows that the job was pumped as designed, indicating competent cementing operations. 12.5 ppg MPII was pumped before dropping bottom plug, this was then chased with 270 bbls of 15.8 ppg Class G cement and the top plug was dropped. This was chased with 9.4 ppg LSND mud. The plug bumped, pressured up to 1500 psi and held for 5 min. Floats were checked and they held. Full returns were seen throughout the job. A TOC was then logged and determined at 8,228’MD/3,967’ TVD/3,904’ TVDSS (pg. 274 at the link below). 218-103 - Laserfiche WebLink 3S-612: The 7-5/8” casing cement report on 11/4/2018 shows that the job was pumped as designed, indicating competent cementing operations. 12.5 ppg MPII was pumped before dropping bottom plug, this was then chased with 303bbls of 15.8 ppg Class G cement and the top plug was dropped. This was chased with 9.5 ppg LSND mud. The plug bumped, pressured up to 1500 psi and held for 5 min. Floats were checked and they held. Full returns were seen throughout the job. A TOC was then logged and determined at 8,270’MD/3,832’ TVD/3,768’ TVDSS (pg. 289 at the link below). 218-111 - Laserfiche WebLink 3S-613: The 7-5/8” casing cement report on 5/2/2016 shows that the 2-string job was pumped as designed, indicating competent cementing operations. The first stage consisted of 47bbls of 15.8ppg cement and plugs bumped and floats held. The second stage consisted of 189bbls of 15.8ppg cement and the plug bumped and floats held. Full returns were seen throughout both jobs. A SonicScope was run to determine TOC, but the log began at estimated TOC and no free ringing pipe was logged to help determine a clear TOC. Interpretation shows a potential TOC at 6,095’ MD/3,711’ TVD/3,646’ TVDSS from the log (pg. 35, 192 at the link below). 216-020 - Laserfiche WebLink 3S-615: The 7-5/8” casing cement report on 11/13/2022 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 200 barrels of 15.3 ppg lead cement with BMII, followed with 33 barrels of 15.3 ppg tail cement, displaced with 524 barrels of 9.6 ppg mud. The plug bumped, bled off pressure and pressure and floats were confirmed to be holding. A cement bond log indicates competent cement with a cement top @ 5,620 MD (3,340’ TVD / 3,279’ TVDSS). 222-101 - Laserfiche WebLink 3S-620: The 7-5/8” casing cement report on 2/6/2015 shows that the job was pumped as designed, indicating competent cementing operations. 11.5 ppg Mud Push II was pumped before dropping bottom plug, this was then chased with 181 bbls of 15.8 ppg Class G cement and the top plug was dropped. This was chased with 9.7 ppg mud. The plug bumped, pressured up to 1500 psi and held for 5 min. Floats were checked and they held. 48bbls of fluid was lost during the job. A SonicScope was run to determine TOC, but the log began at estimated TOC and no free ringing pipe was logged to help determine a clear TOC. Interpretation shows potential TOC above 5,400’ MD/3,567’ TVD/3,514’ TVDSS from the log. 214-167 - Laserfiche WebLink 3S-625: The 7-5/8” casing cement report on 9/29/2022 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 297 barrels of 15.3ppg cement with BMII. The cement was displaced with 574 barrels of 9.6ppg LSND drilling mud. The plug did not bump and 50% of shoe track volume was pumped. Losses totaled 21 barrels during the job. Cement floats held. A cement bond log indicates competent cement with a cement top @ 7,850’ MD (3,970’ TVD / 3,908’ TVDSS). 222-079 - Laserfiche WebLink 3S-626: The 7-5/8” casing cement report on 06/01/2024 shows the job was pumped as designed, indicating competent cementing operations. The cement job was pumped in two stages utilizing a stage tool. The first stage cement job had 188 bbls of 15.3 ppg cement. Plug bumped and floats held. The second stage cement job had 42 bbls of 15.3 ppg cement. Plug bumped and all indications are the stage tool at 6807’ MD closed. A cement bond log run on 06/03/24 indicates competent cement with cement top at 5,908’ MD/3,775’ TVD/3,711’ TVDSS. Due to issues with the freeze protect of the OA, a RWO was performed. The 7-5/8" fish was successfully recovered down to the original cut made with Doyon 142 at 2020 ft MD. A new 7-5/8” casing with a sealing overshot and cementer was installed, and cement was pumped through the cementer to the surface. The 7-5/8" packoff was then installed and tested to 3840 psi, confirming its integrity. 224-007 - Laserfiche WebLink 3S-626PB1: This wellbore was abandoned due to shale collapse in the lateral. A cement retainer was set at 9,198’ MD and 33bbls of 15.3ppg cement was pumped. The TOC was tagged at 8,874’ MD with 10klbs and was witnessed by AOGCC (pg. 128 at link below). A CIBP was set at 3,454’ MD, casing was cut at 3,400’ MD, and the casing was pulled out of hole and laid down. A kick off plug was pumped above the CIBP into the 10-3/4” surface casing with 75bbls of 16.3ppg cement. The 10-3/4” was tested to 1,500 psi for 30 minutes, witnessed by AOGCC (pg. 68 at link below). The TOC was tagged at 2,580’ MD/2,306’ TVD/2,243’ TVDSS with 10klbs, tag witness waived by AOGCC. 224-007 - Laserfiche WebLink 3S-719: The 7-5/8” casing cement report on 7/5/2025 shows that the job was pumped with 90 barrels of 15.3ppg cement. The cement was displaced with 9.5ppg mud. The plugs did not bump, but floats were checked and were holding. Full returns were observed throughout the job. A sonic log indicated the cement top at 7,740’ MD / 3,766’ TVD / 3,702’ TVDSS (2088’ MD / 343’ TVD above the Coyote). 225-058 - Laserfiche WebLink 3S-721: The 7-5/8” casing cement report on 4/29/2025 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 72 barrels of 15.3ppg cement. The cement was displaced with 9.6ppg NAF drilling mud. The plug bumped with 1018 psi and floats held. Full returns were observed during the job. 225-025 - Laserfiche WebLink 3T-603: The 7-5/8” casing cement report on 9/20/2024 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 136 barrels of 14.0 ppg lead cement with BMII, followed with 31 barrels of 15.3 ppg tail cement, displaced with 408.5 barrels of 9.5 ppg FWP. The plug bumped and floats held. A cement bond log run indicates competent cement with a cement top @ 5,692’ MD (3,578’ TVD/3,527’ TVDSS). 224-074 - Laserfiche WebLink 3T-608: The 7-5/8” casing cement report on 10/28/2024 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 203 barrels of 14.0 ppg lead cement with BMII, followed with 31 barrels of 15.3 ppg tail cement, displaced with 463 barrels of 9.5 ppg FWP. The plug bumped, bled off pressure and pressure and floats were confirmed to be holding. A cement bond log indicates competent cement with a cement top @ 5,768 MD (3,843’ TVD/3,792’ TVDSS). 224-094 - Laserfiche WebLink 3T-612: The 7-5/8” casing cement report on 12/07/2024 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 98 barrels of 14.0 ppg lead cement, followed with 58 barrels of 15.3 ppg tail cement. This was displaced with 375 barrels of 9.5 ppg BaraECD NAF. The plug bumped, pressure was bled off, and floats were confirmed to be holding. A cement bond log indicates competent cement with a cement top @ 4,799 MD (3,489’ TVD/3,438’ TVDSS). 224-128 - Laserfiche WebLink 3T-616: The 7-5/8” casing cement report on 01/24/2025 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 117 barrels of 14.0 ppg lead cement with BMII, followed with 58 barrels of 15.3 ppg tail cement. This was displaced with 405 barrels of 9.5 ppg BaraECD NAF. The plug bumped, pressure was bled off, and floats were confirmed to be holding. A cement bond log indicates competent cement with a cement top @ 5,041 MD (3,422’ TVD/3,370’ TVDSS). The 4-1/2” liner cement report on 03/06/2025 shows the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 310 barrels of 14.8 ppg cement. The cement was displaced with 9.5ppg CI NaCl brine and the plugs bumped and held for 5 minutes. Floats held. 224-138 - Laserfiche WebLink 3T-616PB1: This wellbore was drilled in the Torok pool and was abandoned on 2/21/2025 with 42bbls of 16.3ppg cement laid in at the heel of the wellbore into the 7-5/8” intermediate casing shoe. The cement top was then tagged at 9,065’ MD/5,104’ TVD/5,053’ TVDSS with 12klbs. 224-138 - Laserfiche WebLink 3T-616PB2: This wellbore is sidetrack from the 3T-616PB1. The TD of this sidetrack is 12,440’ MD/4,758’ TVD/4,707’ TVDSS. This sidetrack did not exit the Torok pool, but did enter the Torok shale. 224-138 - Laserfiche WebLink 3T-621: The 7-5/8” casing cement report on 05/05/2024 shows the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 82 bbls of 15.3 ppg cement. Plugs bumped and floats held. A cement bond log run on 05/06/24 indicates competent cement with cement top at 6,530’ MD/3,708’ TVD/3,668’ TVDSS. 224-022 - Laserfiche WebLink 3T-730: The 7-5/8” x 4-1/2” casing cement report on 4/30/2025 shows that the job was pumped with 60 barrels of 13.5ppg clean cement, 530 bbls of 13.5ppg cement with Bridge Maker II, and 60 bbls of 13.5ppg clean tail cement. The cement was displaced with 9.7ppg CI brine. The plug bumped and pressure was held at 1150 psi for 5 minutes. Pressure was then bled off and floats checked with floats holding. No losses were observed during the job. A cement bond log indicated the cement top at 4,520’ MD / 3,949’ TVD (507’ MD / 153’ TVD above the Coyote). 225-010 - Laserfiche WebLink Moraine 1: The cement report on 3/3/2015 shows that the 8-1/2” hole was abandoned with 3x plugs starting at 5,610’ MD (TD). A total of 849 sx of 15.8ppg Class G cement was used to set all three plugs. The top cement plug was then tagged at 3,687’ MD/3,643’ TVD/3,600’ TVDSS with 15klbs, witnessed by the AOGCC (pg. 132 at link below). This tag is above the Coyote top at 4,127’ MD. A cement retainer was then set at 2,362’ MD and 21bbls of 15.8ppg Class G slurry was pumped below and 3 bbls above the retainer. A final plug was laid above a CIBP set at 508’ MD to surface using 11ppg AS1 cement. Photos of the final abandonment and marker plate and the submittal to AOGCC are on pages 100-104 at the link below. 214-198 - Laserfiche WebLink NDST-02: According to the Pioneer Natural Resources Operation Summary Report on the AOGCC website, the 7-5/8” casing was cemented on 2/8/2013. The cement report indicates that the job was pumped with 60 bbls of 15.8ppg Premium Cement with 3% Halad (R)-344 low fluid loss control. Full circulation was seen throughout the entire job. A USIT confirmed TOC at 8672' MD/4,841’ TVD/4,800’ TVDSS. Frac operations could not be completed because a lodged ball damaged the tubing, and 60 bbl of CaCO3 was spotted on 4/13/2013. On 4/14/2013, XX plug was set in nipple at 4,550’ WLMD. ConocoPhillips Alaska Inc. re-entered on 1/3/2023, pulled the XX plug at 8,360’ CTMD (restriction) instead of at the nipple and performed injectivity test at 0.5 bpm on 1/21/2023. The tubing was cut at 8,316’ MD and was removed from the well. On 10/8/2024, coil tubing set a cement retainer at 10,441’ MD and pumped 110bbls of 15.8ppg cement into the 4.5” liner. Coil unstung from the retainer and laid an additional 68bbls of 15.8ppg cement on top of the retainer. The cement plug was not tagged due to issues with deviation/thick fluid, but a pressure test was completed to 1700 psi and witness by AOGCC on 10/12/2024 (pg. 2-6 at link below). Another attempt to tag the TOC was completed on 2/8/2025 with coil tubing, tagging at 8,812’ MD with 4klbs and witnessed by AOGCC (pg. 1 at link below). The well is currently awaiting perf/wash/cement operations. The Coyote is not currently isolated by cement in the 7-5/8” x 10-3/4” annulus. The outer annulus of this well (7-5/8” x 10-3/4”) will be monitored during the stimulation of 3T-731. Given the longitudinal orientation of the planned stimulation operations, it is not foreseen that the hydraulic fractures will intersect the Nuna 1 wellbore in the Coyote sand. 212-163 - Laserfiche WebLink NDST-02 PB1: According to the Pioneer Natural Resources Operation Summary Report on the AOGCC website, on 1/30/2013, the bottom plug was pumped with 52bbls of 15.8ppg premium cement. Plug #2 was placed at 8,600’ MD with 52bbls of 15.8ppg premium cement. TOC was tagged at 8,012’ MD with 30klbs. On 1/31/2013, the kick off plug was pumped with 60 bbls of 17ppg premium Class G cement. Tagged firm cement at 5,236’ MD/3,228’ TVD/3,186’ TVDSS with 20klbs on 2/2/2013. 212-163 - Laserfiche WebLink Nuna 1: According to the Pioneer Natural Resources job log on the AOGCC website, the 7-5/8” casing was cemented in place on 2/16/2012. The cement report indicates that the job was pumped with 40 bbls 15.8ppg Class G cement. The plugs bumped and partial returns were observed during the job (pg. 187 at link below). A log was run to interpret TOC which has been indicated as 7,040’ MD/4,860’ TVD/4,817’ TVDSS (pg. 167 at link below). Suspension operations began on 1/18/2023 where a cement retainer was set at 9,062’ CTMD and 65bbls of Class G cement was pumped through the retainer. Another retainer was placed at 7,965’ MD and 48bbls of 15.8ppg cement was pumped with another 12 bbls laid on top of the retainer. The TOC was tagged at 7,003’ MD and a MIT-T performed to 1700 psi, witnessed by AOGCC on 3/1/2023. A tubing cut was completed at 6,960’ MD and the 4.5” tubing was then pulled. A CIBP was set at 6,910’ MD and tested to 1,200 psi. Cement was laid on top of the retainer and tagged at 6,621’ MD two times with 12klbs. The Coyote is not currently isolated with cement. The outer annulus of this well (7-5/8” x 10-3/4”) will be monitored during the stimulation of 3T-731. Given the longitudinal orientation of the planned stimulation operations, it is not foreseen that the hydraulic fractures will intersect the Nuna 1 wellbore in the Coyote sand. 211-155 - Laserfiche WebLink Nuna 1 PB1: According to the Pioneer Natural Resources job log on the AOGCC website, three abandonment plugs were placed on 2/10/2012. The three plugs were set as balanced plugs at the following depths: 7,347’- 6,847’ MD with 52 bbls of 15.8ppg Class G cement, 6,847’-6,285’ MD with 60bbls of 15.8ppg Class G cement, and 6,285’-5,800’ MD with 49bbls of 17.0ppg Class G cement. The top plug was tagged with 25klbs at 5,790’ MD/4,192’ TVD/4,149’ TVDSS prior to kick off for the main wellbore (pg. 186-187 at link below). 211-155 - Laserfiche WebLink SECTION 11 – LOCATION OF, ORIENTATION OF AND GEOLOGICAL DATA FOR FAULTS AND FRACTURES THAT MAY TRANSECT THE CONFINING ZONES 20 AAC 25.283(a)(11) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that three faults transect the Coyote reservoir within one half mile radius of the 3T-731B wellbore trajectory. The first of these faults intersects the 3T-731B wellbore at ~5,711’ MD. This fault is interpreted to have minimal throw at this location (< 5 feet). This fault has an interpreted W – E strike and is downthrown to the South. There is no mapped offset at the Top Coyote based on seismic in the area where it is picked in the 3T-731B wellbore. The second mapped fault intersected the original 3T-731 wellbore at 11,700’ MD, however there was no clear evidence from logs that this fault was present in the 3T-731B wellbore. The fault at 11,700’ MD was interpreted to have a throw of 10 – 20’ where it intersected the original 3T-731 wellbore. This fault has an interpreted ~W – E strike and is downthrown to the south. The third fault is east of the heel of the 3T-731B wellbore. This fault is a west - east striking feature. It is questionable as to whether it is an actual fault at the top Coyote level. If it exists, it has minimal throw at the top Coyote (5 to 10 feet). It has maximum potential offset of ~65’ in the Seabee section ~370’ above the Coyote. It loses throw both upward and downward from this point to near zero at the Coyote level and upward to no throw within in the slope deposits of the upper Seabee formation ~650’ above top Coyote. These faults are interpreted to lose throw into the confining intervals above and below the Coyote reservoir. The interpreted faults should not affect overburden integrity and therefore their presence should not interfere with containment. If there is any indication that a propagated fracture has intersected the mapped fault (or any other faults unmapped to date) during fracturing operations, ConocoPhillips will go to flush and terminate the stage immediately. SECTION 12 – PROPOSED HYDRAULIC FRACTURING PROGRAM 20 AAC 25.283(a)(12) 3T-731 B was completed in 2025 as a horizontal producer in the Coyote formation. The well is a re-drill from the original 3T-731, the well was sidetracked from the 10-3/4” shoe of the original wellbore and completed as a 3- string well. The well was completed with a 4.5” tubing upper completion and 4-1/2” production liner with dart actuated sliding sleeves in the lateral. Injection will be established into the well and the first stage treated. A dart will be dropped for stage 2 to initiate treatment. Once each stage is complete, a dart will be dropped for each subsequent stage. These darts will provide isolation from the previous stage and allow fracturing from the toe of the well towards the heel. Proposed Procedure: Halliburton Pumping Services: 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre- existing conditions. 2. Ensure the frac tree was tested to 10,000 psi on the rig. 3. Ensure all pre-frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to ~2,000’ TVD. 4. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 5. MIRU 25 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 100ºF seawater. 6. MIRU HES Frac Equipment. 7. PT Surface lines to 10,000 psi using a pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Bring up pumps and increase annulus pressure to 3,500 psi as the tubing pressures up. 10. Pump the frac job per the attached Halliburton pump schedule at 20-22 bpm with a maximum expected treating pressure of 7,075 psi. 11. RDMO Halliburton Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 12. The well is ready for post-frac well prep/production tree installation and flowback (after Slickline and Coiled Tubing Cleanout). Patina tracers Will be pumped in the toe and Resmetrics oil and gas tracers will be pumped in remaining stages. See Halliburton chemical disclosure sheet which includes this other chemicals. Frac Model Result Hydraulic Fracturing Fluid Product Component Information Disclosure 2025-12-01 Alaska HARRISON BAY 50-103-2090502-00 CONOCOPHILLIPS 3T 731B -150.26922564 70.41991874 NAD83 none Oil 4200 984816 Hydraulic Fracturing Fluid Composition: Trade Name Supplier Purpose Ingredients Chemical Abstract Service Number (CAS #) Maximum Ingredient Concentration in Additive (% by mass)** Maximum Ingredient Concentration in HF Fluid (% by mass)** Ingredient Mass lbs Comments Company First Name Last Name Email Phone SEAWATER Operator Base Fluid Density = 8.34 BA-20 BUFFERING AGENT Halliburton Buffer BC-140 X2 Halliburton Initiator BE-6(TM) Bactericide Halliburton Microbiocide CAT-3 ACTIVATOR Halliburton Activator CL-28M CROSSLINKER Halliburton Crosslinker CLA-WEB(TM) Halliburton Clay Stabilizer Legend LD-6450 MultiChem Completion/Stimulatio n LoSurf-300D Halliburton Non-ionic Surfactant MO-67 Halliburton pH Control OPTIFLO-HTE Halliburton Breaker OPTIFLO-II DELAYED RELEASE BREAKER Halliburton Breaker OPTIFLO-III DELAYED RELEASE BREAKER Halliburton Breaker ResMetrics Oil Phase Tracer ResMetrics Tracer ResMetrics Water Phase Tracer ResMetrics Tracer SP BREAKER Halliburton Breaker WG-36 GELLING AGENT Halliburton Gelling Agent Ceramic Proppant - Wanli Wanli Proppant SAND, COMMON BROWN 100 MESH Halliburton Proppant Calcium Chloride Customer Salt Solution CarboLite 16/20 Carbo Ceramics Proppant Flow Insurance Brass Patina Energy Tracer Patina Energy Flow Insurance Copper Patina Energy Tracer Ingredients Water 7732-18-5 100.00%69.63774%8213366 Ceramic Materials and Wares, Chemicals 66402-68-4 100.00%29.65810%3498000 Sodium chloride 7647-14-5 5.00%3.48189%410669 Water 7732-18-5 100.00%0.24312%28675 Guar gum 9000-30-0 100.00%0.22389%26407 Calcium Chloride 10043-52-4 100.00%0.08479%10000 Calcium chloride, dihyrate 10035-04-8 60.00%0.05324%6279 EDTA/Copper chelate Proprietary 30.00%0.04149%4894 Denise Tuck, Halliburton, 3000 N. Sam Houston Pkwy E., Houston, TX 77032, 281-871- 6226 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 Ethanol 64-17-5 60.00%0.03781%4460 Monoethanolamine borate 26038-87-9 100.00%0.03515%4146 Oxyalkylated nonyl phenolic resin Proprietary 30.00%0.01891%2230 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 Heavy aromatic petroleum naphtha 64742-94-5 30.00%0.01891%2230 Ammonium persulfate 7727-54-0 100.00%0.01659%1957 Sodium hydroxide 1310-73-2 30.00%0.01220%1440 Ethylene glycol 107-21-1 70.00%0.01134%1337 Ammonium chloride 12125-02-9 5.00%0.00692%816 Oxyalkylated phenolic resin Proprietary 10.00%0.00630%744 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 Corundum 1302-74-5 60.00%0.00509%600 Oxylated phenolic resin Proprietary 30.00%0.00498%588 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 Copolymer of acrylamide and sodium acrylate 25085-02-3 5.00%0.00444%524 Mullite 1302-93-8 40.00%0.00339%400 Naphthalene 91-20-3 5.00%0.00315%372 Poly(oxy-1,2-ethanediyl), alpha-(4- nonylphenyl)-omega-hydroxy-, branched 127087-87-0 5.00%0.00315%372 Crystalline silica, quartz 14808-60-7 100.00%0.00167%198 Ammonia 7664-41-7 1.00%0.00138%164 2-Bromo-2-nitro-1,3-propanediol 52-51-7 100.00%0.00125%147 Glycol Ether Proprietary 80.00%0.00091%107 ResMetrics Product Stewardship info@resmetri cs.com 8325921900 1,2,4 Trimethylbenzene 95-63-6 1.00%0.00063%75 Sodium chloride 7647-14-5 1.00%0.00041%49 Proprietary Non-Hazardous Proprietary 100.00%0.00037%45 Patina Energy Julie Harrish julie@patinae nergy.com 8327140836 Flow Insurance Brass Proprietary 100.00%0.00037%44 Patina Energy Julie Harrish julie@patinae nergy.com 8327140836 Proprietary1 Proprietary 20.00%0.00034%41 ResMetrics Product Stewardship info@resmetri cs.com 8325921900 C.I. pigment Orange 5 3468-63-1 1.00%0.00017%20 Polymer Proprietary 0.10%0.00009%11 MultiChem Ana Djuric Ana.Djuric@H alliburton.com 281-871- 5747 Ammonium acetate 631-61-8 100.00%0.00008%10 Borate salts Proprietary 60.00%0.00005%7 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 Ammonium salt Proprietary 60.00%0.00005%6 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 2,7-Naphthalenedisulfonic acid, 3- hydroxy-4-[(4-sulfor-1- naphthalenyl) azo] -, trisodium salt 915-67-3 0.10%0.00004%5 Acetic acid 64-19-7 30.00%0.00002%3 Sodium persulfate 7775-27-1 100.00%0.00001%1 Walnut hulls NA 100.00%0.00001%1 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 Inorganic mineral 1317-65-3 5.00%0.00000%1 Potassium chloride 7447-40-7 5.00%0.00000%1 Polyamine Proprietary 30.00%0.00000%1 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 Inorganic mineral Proprietary 1.00%0.00000%1 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 Polymer Proprietary 1.00%0.00000%1 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 Gluteraldehyde 111-30-8 1.00%0.00000%1 Calcium magnesium carbonate 16389-88-1 1.00%0.00000%1 Hemicellulase 9025-56-3 5.00%0.00000%1 Methanesulfonic acid, 1-hydroxy-, sodium salt 870-72-4 0.10%0.00000%1 Sodium bisulfate 7681-38-1 0.10%0.00000%1 Cured acrylic resin Proprietary 1.00%0.00000%1 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 C.I. Pigment Red 5 6410-41-9 1.00%0.00000%1 Quaternary amine Proprietary 0.10%0.00000%1 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 Amine salts Proprietary 0.10%0.00000%1 Halliburton Denise Tuck Denise.Tuck @Halliburton. com 281-871- 6226 2-Methyl-4-isothiazolin-3-one 2682-20-4 0.01%0.00000%1 5-Chloro-2-methyl-3(2H)- Isothaiazolone 26172-55-4 0.01%0.00000%1 Magensium chloride 7786-30-3 0.01%0.00000%1 Magnesium nitrate 10377-60-3 0.01%0.00000%1 Sodium sulfate 7757-82-6 0.10%0.00000%1 * Total Water Volume sources may include fresh water, produced water, and/or recycled water ** Information is based on the maximum potential for concentration and thus the total may be over 100% Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided.Version web 1.5 All component information listed was obtained from the supplier’s Material Safety Data Sheets (MSDS). As such, the Operator is not responsible for inaccurate and/or incomplete information. Any questions regarding the content of the MSDS should be directed to the supplier who provided it. The Occupational Safety and Health Administration’s (OSHA) regulations govern the criteria for the disclosure of this information. Please note that Federal Law protects "proprietary", "trade secret", and "confidential business information" and the criteria for how this information is reported on an MSDS is subject to 29 CFR 1910.1200(i) and Appendix D. Production Type: True Vertical Depth (TVD): Total Water Volume (gal)*: MSDS and Non-MSDS Ingredients are listed below the green line Well Name and Number: Longitude: Latitude: Long/Lat Projection: Indian/Federal: Fracture Date State: County: API Number: Operator Name: CU S T O M E R Co n o c o P h i l l i p s FA L S E AP I BF D (l b / g a l ) 8. 5 4 LA T 70 . 4 1 9 9 1 8 7 4 LE A S E 3T - 7 3 1 L 2 SA L E S O R D E R BH S T (° F ) 10 5 LO N G -1 5 0 . 2 6 9 2 2 5 6 FO R M A T I O N Co y o t e DA T E M a x P r e s s u r e ( p s i ) 85 0 0 *E x c e e d s 8 0 % o f b u r s t p r e s s u r e * Pr o p S l u r r y D e s i g n C l e a n D e s i g n C l e a n D e s i g n S l u r r y D e s i g n P r o p S t a g e I n t e r v a l B C - 1 4 0 X 2 L o s u r f - 3 0 0 D M O - 6 7 C A T - 3 L D - 6 4 5 0 W G - 3 6 O P T I F L O - I I BE - 6 Tr e a t m e n t St a g e F l u i d S t a g e P r o p p a n t C o n c R a t e V o l u m e V o l u m e V o l u m e T o t a l T i m e T i m e Cr o s s l i n k e r S u r f a c t a n t B u f f e r C a t a l y s t C l a y C o n t r o l In t e r v a l N u m b e r D e s c r i p t i o n D e s c r i p t i o n D e s c r i p t i o n (p p g ) ( b p m ) ( g a l ) ( b b l ) ( b b l ) ( l b s ) ( h h : m m : s s ) ( h h : m m : s s ) (g p t ) ( g p t ) ( g p t ) ( g p t ) ( g p t ) ( p p t ) ( p p t ) ( p p t ) 1- 1 S h u t - I n S h u t - I n 1: 5 9 : 5 4 1- 2 F r e e z e P r o t e c t P r i m e U p P r e s s u r e T e s t 5 1 , 0 0 0 2 4 2 4 0 : 0 4 : 4 6 1 : 5 9 : 5 4 1- 3 S h u t - I n S h u t - I n 1: 5 5 : 0 8 1- 4 2 7 # L i n e a r D F I T 1 0 1 , 6 8 0 4 0 4 0 0 : 0 4 : 0 0 1 : 5 5 : 0 8 1 . 0 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 1- 5 S h u t - I n S h u t - I n 1: 5 1 : 0 8 1- 6 2 7 # D e l t a F r a c E s t a b l i s h S t a b l e F l u i d 1 5 8 , 4 0 0 2 0 0 2 0 0 0 : 1 3 : 2 0 1 : 5 1 : 0 8 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 1- 7 2 7 # D e l t a F r a c P a d 2 0 1 6 , 4 3 0 3 9 1 3 9 1 0 : 1 9 : 3 4 1 : 3 7 : 4 8 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 1- 8 2 7 # D e l t a F r a c C o n d i t i o n i n g P a d 1 6 / 2 0 C e r a m i c 0 . 5 0 2 0 6 , 0 0 0 1 4 3 1 4 6 3 , 0 0 0 0 : 0 7 : 1 8 1 : 1 8 : 1 5 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 1- 9 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 2 . 0 0 2 0 3 , 8 5 0 9 2 1 0 0 7 , 7 0 0 0 : 0 5 : 0 0 1 : 1 0 : 5 6 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 1- 1 0 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 4 . 0 0 2 0 6 , 4 0 0 1 5 2 1 8 0 2 5 , 6 0 0 0 : 0 9 : 0 1 1 : 0 5 : 5 6 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 1- 1 1 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 6 . 0 0 2 0 6 , 2 0 0 1 4 8 1 8 7 3 7 , 2 0 0 0 : 0 9 : 2 4 0 : 5 6 : 5 6 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 1- 1 2 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 7 . 0 0 2 0 9 , 7 0 0 2 3 1 3 0 3 6 7 , 9 0 0 0 : 1 5 : 1 4 0 : 4 7 : 3 2 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 1- 1 3 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 8 . 0 0 2 0 8 , 7 0 0 2 0 7 2 8 1 6 9 , 6 0 0 0 : 1 4 : 0 8 0 : 3 2 : 1 8 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 1- 1 4 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 9 . 0 0 2 0 6 , 0 0 0 1 4 3 2 0 0 5 4 , 0 0 0 0 : 1 0 : 0 4 0 : 1 8 : 1 0 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 1- 1 5 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 1 0 . 0 0 2 0 3 , 8 0 0 9 0 1 3 1 3 8 , 0 0 0 0 : 0 6 : 3 5 0 : 0 8 : 0 5 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 1- 1 6 2 7 # L i n e a r S p a c e r a n d D a r t D r o p 2 0 1 , 2 6 0 3 0 3 0 0 : 0 1 : 3 0 0 : 0 1 : 3 0 1 . 0 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0 . 1 5 2- 1 2 7 # L i n e a r P r e - P a d 2 0 2 , 1 0 0 5 0 5 0 0 : 0 2 : 3 0 1 : 5 0 : 1 8 1 . 0 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 2- 2 2 7 # D e l t a F r a c E s t a b l i s h S t a b l e F l u i d 2 0 8 , 4 0 0 2 0 0 2 0 0 0 : 1 0 : 0 0 1 : 4 7 : 4 8 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 2- 3 2 7 # D e l t a F r a c P a d 2 0 1 6 , 4 3 0 3 9 1 3 9 1 0 : 1 9 : 3 4 1 : 3 7 : 4 8 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 2- 4 2 7 # D e l t a F r a c C o n d i t i o n i n g P a d 1 6 / 2 0 C e r a m i c 0 . 5 0 2 0 6 , 0 0 0 1 4 3 1 4 6 3 , 0 0 0 0 : 0 7 : 1 8 1 : 1 8 : 1 5 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 2- 5 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 2 . 0 0 2 0 3 , 8 5 0 9 2 1 0 0 7 , 7 0 0 0 : 0 5 : 0 0 1 : 1 0 : 5 6 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 2- 6 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 4 . 0 0 2 0 6 , 4 0 0 1 5 2 1 8 0 2 5 , 6 0 0 0 : 0 9 : 0 1 1 : 0 5 : 5 6 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 2- 7 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 6 . 0 0 2 0 6 , 2 0 0 1 4 8 1 8 7 3 7 , 2 0 0 0 : 0 9 : 2 4 0 : 5 6 : 5 6 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 2- 8 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 7 . 0 0 2 0 9 , 7 0 0 2 3 1 3 0 3 6 7 , 9 0 0 0 : 1 5 : 1 4 0 : 4 7 : 3 2 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 2- 9 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 8 . 0 0 2 0 8 , 7 0 0 2 0 7 2 8 1 6 9 , 6 0 0 0 : 1 4 : 0 8 0 : 3 2 : 1 8 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 2- 1 0 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 9 . 0 0 2 0 6 , 0 0 0 1 4 3 2 0 0 5 4 , 0 0 0 0 : 1 0 : 0 4 0 : 1 8 : 1 0 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 2- 1 1 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 1 0 . 0 0 2 0 3 , 8 0 0 9 0 1 3 1 3 8 , 0 0 0 0 : 0 6 : 3 5 0 : 0 8 : 0 5 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 2- 1 2 2 7 # L i n e a r S p a c e r a n d D a r t D r o p 2 0 1 , 2 6 0 3 0 3 0 0 : 0 1 : 3 0 0 : 0 1 : 3 0 1 . 0 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0 . 1 5 3- 1 2 7 # L i n e a r P r e - P a d 2 0 2 , 1 0 0 5 0 5 0 0 : 0 2 : 3 0 1 : 5 0 : 1 8 1 . 0 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 3- 2 2 7 # D e l t a F r a c E s t a b l i s h S t a b l e F l u i d 2 0 8 , 4 0 0 2 0 0 2 0 0 0 : 1 0 : 0 0 1 : 4 7 : 4 8 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 3- 3 2 7 # D e l t a F r a c P a d 2 0 1 6 , 4 3 0 3 9 1 3 9 1 0 : 1 9 : 3 4 1 : 3 7 : 4 8 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 3- 4 2 7 # D e l t a F r a c C o n d i t i o n i n g P a d 1 6 / 2 0 C e r a m i c 0 . 5 0 2 0 6 , 0 0 0 1 4 3 1 4 6 3 , 0 0 0 0 : 0 7 : 1 8 1 : 1 8 : 1 5 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 3- 5 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 2 . 0 0 2 0 3 , 8 5 0 9 2 1 0 0 7 , 7 0 0 0 : 0 5 : 0 0 1 : 1 0 : 5 6 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 3- 6 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 4 . 0 0 2 0 6 , 4 0 0 1 5 2 1 8 0 2 5 , 6 0 0 0 : 0 9 : 0 1 1 : 0 5 : 5 6 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 3- 7 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 6 . 0 0 2 0 6 , 2 0 0 1 4 8 1 8 7 3 7 , 2 0 0 0 : 0 9 : 2 4 0 : 5 6 : 5 6 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 3- 8 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 7 . 0 0 2 0 9 , 7 0 0 2 3 1 3 0 3 6 7 , 9 0 0 0 : 1 5 : 1 4 0 : 4 7 : 3 2 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 3- 9 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 8 . 0 0 2 0 8 , 7 0 0 2 0 7 2 8 1 6 9 , 6 0 0 0 : 1 4 : 0 8 0 : 3 2 : 1 8 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 3- 1 0 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 9 . 0 0 2 0 6 , 0 0 0 1 4 3 2 0 0 5 4 , 0 0 0 0 : 1 0 : 0 4 0 : 1 8 : 1 0 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 3- 1 1 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 1 0 . 0 0 2 0 3 , 8 0 0 9 0 1 3 1 3 8 , 0 0 0 0 : 0 6 : 3 5 0 : 0 8 : 0 5 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 3- 1 2 2 7 # L i n e a r S p a c e r a n d D a r t D r o p 2 0 1 , 2 6 0 3 0 3 0 0 : 0 1 : 3 0 0 : 0 1 : 3 0 1 . 0 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0 . 1 5 4- 1 2 7 # L i n e a r P r e - P a d 2 0 2 , 1 0 0 5 0 5 0 0 : 0 2 : 3 0 2 : 0 3 : 3 1 1 . 0 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 4- 2 2 7 # D e l t a F r a c E s t a b l i s h S t a b l e F l u i d 2 0 8 , 4 0 0 2 0 0 2 0 0 0 : 1 0 : 0 0 2 : 0 1 : 0 1 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 4- 3 2 7 # D e l t a F r a c P a d 2 0 1 6 , 4 3 0 3 9 1 3 9 1 0 : 1 9 : 3 4 1 : 5 1 : 0 1 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 4- 4 2 7 # D e l t a F r a c C o n d i t i o n i n g P a d 1 6 / 2 0 C e r a m i c 0 . 5 0 2 0 6 , 0 0 0 1 4 3 1 4 6 3 , 0 0 0 0 : 0 7 : 1 8 1 : 3 1 : 2 7 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 4- 5 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 2 . 0 0 2 0 3 , 8 5 0 9 2 1 0 0 7 , 7 0 0 0 : 0 5 : 0 0 1 : 2 4 : 0 9 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 4- 6 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 4 . 0 0 2 0 6 , 4 0 0 1 5 2 1 8 0 2 5 , 6 0 0 0 : 0 9 : 0 1 1 : 1 9 : 0 9 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 4- 7 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 6 . 0 0 2 0 6 , 2 0 0 1 4 8 1 8 7 3 7 , 2 0 0 0 : 0 9 : 2 4 1 : 1 0 : 0 8 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 4- 8 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 7 . 0 0 2 0 9 , 7 0 0 2 3 1 3 0 3 6 7 , 9 0 0 0 : 1 5 : 1 4 1 : 0 0 : 4 4 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 4- 9 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 8 . 0 0 2 0 8 , 7 0 0 2 0 7 2 8 1 6 9 , 6 0 0 0 : 1 4 : 0 8 0 : 4 5 : 3 0 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 4- 1 0 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 9 . 0 0 2 0 6 , 0 0 0 1 4 3 2 0 0 5 4 , 0 0 0 0 : 1 0 : 0 4 0 : 3 1 : 2 2 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 4- 1 1 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 1 0 . 0 0 2 0 3 , 8 0 0 9 0 1 3 1 3 8 , 0 0 0 0 : 0 6 : 3 5 0 : 2 1 : 1 8 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 4- 1 2 2 7 # L i n e a r F l u s h 2 0 7 , 3 1 7 1 7 4 1 7 4 0 : 0 8 : 4 3 0 : 1 4 : 4 3 1 . 0 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 4- 1 3 F r e e z e P r o t e c t F r e e z e P r o t e c t 5 1 , 2 6 0 3 0 3 0 0 : 0 6 : 0 0 0 : 0 6 : 0 0 4- 1 4 S h u t - I n S h u t - I n 5- 1 S h u t - I n S h u t - I n 2: 0 7 : 0 1 5- 2 F r e e z e P r o t e c t P r i m e U p P r e s s u r e T e s t 5 1 , 0 0 0 2 4 2 4 0 : 0 4 : 4 6 2 : 0 7 : 0 1 5- 3 S h u t - I n S h u t - I n 2: 0 2 : 1 5 5- 4 2 7 # L i n e a r S p a c e r a n d D a r t D r o p 1 5 6 , 9 9 9 1 6 7 1 6 7 0 : 1 1 : 0 7 2 : 0 2 : 1 5 1 . 0 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 5- 5 2 7 # D e l t a F r a c E s t a b l i s h S t a b l e F l u i d 1 5 8 , 4 0 0 2 0 0 2 0 0 0 : 1 3 : 2 0 1 : 5 1 : 0 8 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 5- 6 2 7 # D e l t a F r a c P a d 2 0 1 6 , 4 3 0 3 9 1 3 9 1 0 : 1 9 : 3 4 1 : 3 7 : 4 8 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 5- 7 2 7 # D e l t a F r a c C o n d i t i o n i n g P a d 1 6 / 2 0 C e r a m i c 0 . 5 0 2 0 6 , 0 0 0 1 4 3 1 4 6 3 , 0 0 0 0 : 0 7 : 1 8 1 : 1 8 : 1 5 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 5- 8 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 2 . 0 0 2 0 3 , 8 5 0 9 2 1 0 0 7 , 7 0 0 0 : 0 5 : 0 0 1 : 1 0 : 5 6 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 5- 9 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 4 . 0 0 2 0 6 , 4 0 0 1 5 2 1 8 0 2 5 , 6 0 0 0 : 0 9 : 0 1 1 : 0 5 : 5 6 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 5- 1 0 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 6 . 0 0 2 0 6 , 2 0 0 1 4 8 1 8 7 3 7 , 2 0 0 0 : 0 9 : 2 4 0 : 5 6 : 5 6 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 5- 1 1 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 7 . 0 0 2 0 9 , 7 0 0 2 3 1 3 0 3 6 7 , 9 0 0 0 : 1 5 : 1 4 0 : 4 7 : 3 2 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 5- 1 2 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 8 . 0 0 2 0 8 , 7 0 0 2 0 7 2 8 1 6 9 , 6 0 0 0 : 1 4 : 0 8 0 : 3 2 : 1 8 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 5- 1 3 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 9 . 0 0 2 0 6 , 0 0 0 1 4 3 2 0 0 5 4 , 0 0 0 0 : 1 0 : 0 4 0 : 1 8 : 1 0 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 5- 1 4 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 1 0 . 0 0 2 0 3 , 8 0 0 9 0 1 3 1 3 8 , 0 0 0 0 : 0 6 : 3 5 0 : 0 8 : 0 5 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 5- 1 5 2 7 # L i n e a r S p a c e r a n d D a r t D r o p 2 0 1 , 2 6 0 3 0 3 0 0 : 0 1 : 3 0 0 : 0 1 : 3 0 1 . 0 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0 . 1 5 6- 1 2 7 # L i n e a r P r e - P a d 2 0 2 , 1 0 0 5 0 5 0 0 : 0 2 : 3 0 1 : 5 0 : 1 8 1 . 0 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0 . 1 5 6- 2 2 7 # D e l t a F r a c E s t a b l i s h S t a b l e F l u i d 2 0 8 , 4 0 0 2 0 0 2 0 0 0 : 1 0 : 0 0 1 : 4 7 : 4 8 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0 . 1 5 6- 3 2 7 # D e l t a F r a c P a d 2 0 1 6 , 4 3 0 3 9 1 3 9 1 0 : 1 9 : 3 4 1 : 3 7 : 4 8 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0 . 1 5 6- 4 2 7 # D e l t a F r a c C o n d i t i o n i n g P a d 1 6 / 2 0 C e r a m i c 0 . 5 0 2 0 6 , 0 0 0 1 4 3 1 4 6 3 , 0 0 0 0 : 0 7 : 1 8 1 : 1 8 : 1 5 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0 . 1 5 6- 5 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 2 . 0 0 2 0 3 , 8 5 0 9 2 1 0 0 7 , 7 0 0 0 : 0 5 : 0 0 1 : 1 0 : 5 6 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0 . 1 5 Interval 1 Coyote @ 12983 - 12987 ft 104.7 °F Interval 2 Coyote @ 12440 - 12444 ft 104.7 °F Interval 3 Coyote @ 11944 - 11948 ft 104.7 °F Interval 4 Coyote @ 11447 - 11451 ft 104.7 °F Interval 5 Coyote @ 10949 - 10953 ft 104.6 °F 6 e ft 104.6 °F Li q u i d A d d i t i v e s Dr y A d d i t i v e s 50 - 1 0 3 - 2 0 9 0 5 - 0 1 Co n o c o P h i l l i p s - 3 T - 7 3 1 Pl a n n e d D e s i g n 1 CU S T O M E R Co n o c o P h i l l i p s FA L S E AP I BF D (l b / g a l ) 8. 5 4 LA T 70 . 4 1 9 9 1 8 7 4 LE A S E 3T - 7 3 1 L 2 SA L E S O R D E R BH S T (° F ) 10 5 LO N G -1 5 0 . 2 6 9 2 2 5 6 FO R M A T I O N Co y o t e DA T E M a x P r e s s u r e ( p s i ) 85 0 0 *E x c e e d s 8 0 % o f b u r s t p r e s s u r e * Pr o p S l u r r y D e s i g n C l e a n D e s i g n C l e a n D e s i g n S l u r r y D e s i g n P r o p S t a g e I n t e r v a l B C - 1 4 0 X 2 L o s u r f - 3 0 0 D M O - 6 7 C A T - 3 L D - 6 4 5 0 W G - 3 6 O P T I F L O - I I BE - 6 Tr e a t m e n t St a g e F l u i d S t a g e P r o p p a n t C o n c R a t e V o l u m e V o l u m e V o l u m e T o t a l T i m e T i m e Cr o s s l i n k e r S u r f a c t a n t B u f f e r C a t a l y s t C l a y C o n t r o l In t e r v a l N u m b e r D e s c r i p t i o n D e s c r i p t i o n D e s c r i p t i o n (p p g ) ( b p m ) ( g a l ) ( b b l ) ( b b l ) ( l b s ) ( h h : m m : s s ) ( h h : m m : s s ) (g p t ) ( g p t ) ( g p t ) ( g p t ) ( g p t ) ( p p t ) ( p p t ) ( p p t ) Li q u i d A d d i t i v e s Dr y A d d i t i v e s 50 - 1 0 3 - 2 0 9 0 5 - 0 1 6- 6 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 4 . 0 0 2 0 6 , 4 0 0 1 5 2 1 8 0 2 5 , 6 0 0 0 : 0 9 : 0 1 1 : 0 5 : 5 6 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0 . 1 5 6- 7 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 6 . 0 0 2 0 6 , 2 0 0 1 4 8 1 8 7 3 7 , 2 0 0 0 : 0 9 : 2 4 0 : 5 6 : 5 6 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 6- 8 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 7 . 0 0 2 0 9 , 7 0 0 2 3 1 3 0 3 6 7 , 9 0 0 0 : 1 5 : 1 4 0 : 4 7 : 3 2 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 6- 9 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 8 . 0 0 2 0 8 , 7 0 0 2 0 7 2 8 1 6 9 , 6 0 0 0 : 1 4 : 0 8 0 : 3 2 : 1 8 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 6- 1 0 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 9 . 0 0 2 0 6 , 0 0 0 1 4 3 2 0 0 5 4 , 0 0 0 0 : 1 0 : 0 4 0 : 1 8 : 1 0 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 6- 1 1 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 1 0 . 0 0 2 0 3 , 8 0 0 9 0 1 3 1 3 8 , 0 0 0 0 : 0 6 : 3 5 0 : 0 8 : 0 5 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 6- 1 2 2 7 # L i n e a r S p a c e r a n d D a r t D r o p 2 0 1 , 2 6 0 3 0 3 0 0 : 0 1 : 3 0 0 : 0 1 : 3 0 1 . 0 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0 . 1 5 7- 1 2 7 # L i n e a r P r e - P a d 2 0 2 , 1 0 0 5 0 5 0 0 : 0 2 : 3 0 1 : 5 0 : 1 8 1 . 0 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 7- 2 2 7 # D e l t a F r a c E s t a b l i s h S t a b l e F l u i d 2 0 8 , 4 0 0 2 0 0 2 0 0 0 : 1 0 : 0 0 1 : 4 7 : 4 8 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 7- 3 2 7 # D e l t a F r a c P a d 2 0 1 6 , 4 3 0 3 9 1 3 9 1 0 : 1 9 : 3 4 1 : 3 7 : 4 8 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 7- 4 2 7 # D e l t a F r a c C o n d i t i o n i n g P a d 1 6 / 2 0 C e r a m i c 0 . 5 0 2 0 6 , 0 0 0 1 4 3 1 4 6 3 , 0 0 0 0 : 0 7 : 1 8 1 : 1 8 : 1 5 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 7- 5 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 2 . 0 0 0 0 2 0 3 , 8 5 0 9 2 1 0 0 7 , 7 0 0 0 : 0 5 : 0 0 1 : 1 0 : 5 6 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 7- 6 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 4 . 0 0 2 0 6 , 4 0 0 1 5 2 1 8 0 2 5 , 6 0 0 0 : 0 9 : 0 1 1 : 0 5 : 5 6 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 7- 7 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 6 . 0 0 2 0 6 , 2 0 0 1 4 8 1 8 7 3 7 , 2 0 0 0 : 0 9 : 2 4 0 : 5 6 : 5 6 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 7- 8 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 7 . 0 0 2 0 9 , 7 0 0 2 3 1 3 0 3 6 7 , 9 0 0 0 : 1 5 : 1 4 0 : 4 7 : 3 2 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 7- 9 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 8 . 0 0 2 0 8 , 7 0 0 2 0 7 2 8 1 6 9 , 6 0 0 0 : 1 4 : 0 8 0 : 3 2 : 1 8 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 7- 1 0 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 9 . 0 0 2 0 6 , 0 0 0 1 4 3 2 0 0 5 4 , 0 0 0 0 : 1 0 : 0 4 0 : 1 8 : 1 0 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 7- 1 1 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 1 0 . 0 0 2 0 3 , 8 0 0 9 0 1 3 1 3 8 , 0 0 0 0 : 0 6 : 3 5 0 : 0 8 : 0 5 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 7- 1 2 2 7 # L i n e a r S p a c e r a n d D a r t D r o p 2 0 1 , 2 6 0 3 0 3 0 0 : 0 1 : 3 0 0 : 0 1 : 3 0 1 . 0 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0 . 1 5 8- 1 2 7 # L i n e a r P r e - P a d 2 0 2 , 1 0 0 5 0 5 0 0 : 0 2 : 3 0 1 : 0 2 : 1 4 1 . 0 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 8- 2 2 7 # D e l t a F r a c E s t a b l i s h S t a b l e F l u i d 2 0 8 , 4 0 0 2 0 0 2 0 0 0 : 1 0 : 0 0 0 : 5 9 : 4 4 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 8- 3 2 7 # D e l t a F r a c P a d 2 0 5 , 1 6 5 1 2 3 1 2 3 0 : 0 6 : 0 9 0 : 4 9 : 4 4 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 8- 4 2 7 # D e l t a F r a c C o n d i t i o n i n g P a d 1 6 / 2 0 C e r a m i c 0 . 5 0 0 0 2 0 6 , 0 0 0 1 4 3 1 4 6 3 , 0 0 0 0 : 0 7 : 1 8 0 : 4 3 : 3 5 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 8- 5 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 2 . 0 0 2 0 2 , 0 0 0 4 8 5 2 4 , 0 0 0 0 : 0 2 : 3 6 0 : 3 6 : 1 6 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 8- 6 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 4 . 0 0 2 0 3 , 2 0 0 7 6 9 0 1 2 , 8 0 0 0 : 0 4 : 3 0 0 : 3 3 : 4 1 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 8- 7 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 6 . 0 0 2 0 3 , 1 0 0 7 4 9 4 1 8 , 6 0 0 0 : 0 4 : 4 2 0 : 2 9 : 1 0 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 8- 8 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 7 . 0 0 2 0 4 , 8 0 0 1 1 4 1 5 0 3 3 , 6 0 0 0 : 0 7 : 3 2 0 : 2 4 : 2 8 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 8- 9 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 8 . 0 0 2 0 4 , 3 5 0 1 0 4 1 4 1 3 4 , 8 0 0 0 : 0 7 : 0 4 0 : 1 6 : 5 6 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 8- 1 0 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 9 . 0 0 2 0 3 , 0 0 0 7 1 1 0 0 2 7 , 0 0 0 0 : 0 5 : 0 2 0 : 0 9 : 5 2 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 8- 1 1 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 1 0 . 0 0 2 0 1 , 9 2 0 4 6 6 6 1 9 , 2 0 0 0 : 0 3 : 2 0 0 : 0 4 : 5 0 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 8- 1 2 2 7 # L i n e a r S p a c e r a n d D a r t D r o p 2 0 1 , 2 6 0 3 0 3 0 0 : 0 1 : 3 0 0 : 0 1 : 3 0 1 . 0 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0 . 1 5 9- 1 2 7 # L i n e a r P r e - P a d 2 0 2 , 1 0 0 5 0 5 0 0 : 0 2 : 3 0 1 : 1 3 : 3 3 1 . 0 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 9- 2 2 7 # D e l t a F r a c E s t a b l i s h S t a b l e F l u i d 2 0 8 , 4 0 0 2 0 0 2 0 0 0 : 1 0 : 0 0 1 : 1 1 : 0 3 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 9- 3 2 7 # D e l t a F r a c P a d 2 0 5 , 1 6 5 1 2 3 1 2 3 0 : 0 6 : 0 9 1 : 0 1 : 0 3 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 9- 4 2 7 # D e l t a F r a c C o n d i t i o n i n g P a d 1 6 / 2 0 C e r a m i c 0 . 5 0 2 0 6 , 0 0 0 1 4 3 1 4 6 3 , 0 0 0 0 : 0 7 : 1 8 0 : 5 4 : 5 4 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 9- 5 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 2 . 0 0 2 0 2 , 0 0 0 4 8 5 2 4 , 0 0 0 0 : 0 2 : 3 6 0 : 4 7 : 3 5 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 9- 6 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 4 . 0 0 2 0 3 , 2 0 0 7 6 9 0 1 2 , 8 0 0 0 : 0 4 : 3 0 0 : 4 5 : 0 0 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 9- 7 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 6 . 0 0 2 0 3 , 1 0 0 7 4 9 4 1 8 , 6 0 0 0 : 0 4 : 4 2 0 : 4 0 : 2 9 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 9- 8 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 7 . 0 0 2 0 4 , 8 0 0 1 1 4 1 5 0 3 3 , 6 0 0 0 : 0 7 : 3 2 0 : 3 5 : 4 7 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 9- 9 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 8 . 0 0 2 0 4 , 3 5 0 1 0 4 1 4 1 3 4 , 8 0 0 0 : 0 7 : 0 4 0 : 2 8 : 1 5 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 9- 1 0 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 9 . 0 0 2 0 3 , 0 0 0 7 1 1 0 0 2 7 , 0 0 0 0 : 0 5 : 0 2 0 : 2 1 : 1 1 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 9- 1 1 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 1 0 . 0 0 2 0 1 , 9 2 0 4 6 6 6 1 9 , 2 0 0 0 : 0 3 : 2 0 0 : 1 6 : 0 9 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 9- 1 2 2 7 # L i n e a r F l u s h 2 0 5 , 7 2 6 1 3 6 1 3 6 0 : 0 6 : 4 9 0 : 1 2 : 4 9 1 . 0 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 9- 1 3 F r e e z e P r o t e c t F r e e z e P r o t e c t 5 1 , 2 6 0 3 0 3 0 0 : 0 6 : 0 0 0 : 0 6 : 0 0 9- 1 4 S h u t - I n S h u t - I n 10 - 1 S h u t - I n S h u t - I n 1: 1 3 : 0 9 10 - 2 F r e e z e P r o t e c t P r i m e U p P r e s s u r e T e s t 5 1 , 0 0 0 2 4 2 4 0 : 0 4 : 4 6 1 : 1 3 : 0 9 10 - 3 S h u t - I n S h u t - I n 1: 0 8 : 2 4 10 - 4 2 7 # L i n e a r S p a c e r a n d D a r t D r o p 1 5 1 , 2 6 0 3 0 3 0 0 : 0 2 : 0 0 1 : 0 8 : 2 4 1 . 0 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 10 - 5 2 7 # L i n e a r P r e - P a d 1 5 2 , 1 0 0 5 0 5 0 0 : 0 3 : 2 0 1 : 0 6 : 2 4 1 . 0 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 10 - 6 2 7 # D e l t a F r a c E s t a b l i s h S t a b l e F l u i d 1 5 8 , 4 0 0 2 0 0 2 0 0 0 : 1 3 : 2 0 1 : 0 3 : 0 4 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 10 - 7 2 7 # D e l t a F r a c P a d 2 0 5 , 1 6 5 1 2 3 1 2 3 0 : 0 6 : 0 9 0 : 4 9 : 4 4 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 10 - 8 2 7 # D e l t a F r a c C o n d i t i o n i n g P a d 1 6 / 2 0 C e r a m i c 0 . 5 0 2 0 6 , 0 0 0 1 4 3 1 4 6 3 , 0 0 0 0 : 0 7 : 1 8 0 : 4 3 : 3 5 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 10 - 9 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 2 . 0 0 2 0 2 , 0 0 0 4 8 5 2 4 , 0 0 0 0 : 0 2 : 3 6 0 : 3 6 : 1 6 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 10 - 1 0 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 4 . 0 0 2 0 3 , 2 0 0 7 6 9 0 1 2 , 8 0 0 0 : 0 4 : 3 0 0 : 3 3 : 4 1 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 10 - 1 1 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 6 . 0 0 2 0 3 , 1 0 0 7 4 9 4 1 8 , 6 0 0 0 : 0 4 : 4 2 0 : 2 9 : 1 0 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 10 - 1 2 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 7 . 0 0 2 0 4 , 8 0 0 1 1 4 1 5 0 3 3 , 6 0 0 0 : 0 7 : 3 2 0 : 2 4 : 2 8 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 10 - 1 3 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 8 . 0 0 2 0 4 , 3 5 0 1 0 4 1 4 1 3 4 , 8 0 0 0 : 0 7 : 0 4 0 : 1 6 : 5 6 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 10 - 1 4 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 9 . 0 0 2 0 3 , 0 0 0 7 1 1 0 0 2 7 , 0 0 0 0 : 0 5 : 0 2 0 : 0 9 : 5 2 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 10 - 1 5 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 1 0 . 0 0 2 0 1 , 9 2 0 4 6 6 6 1 9 , 2 0 0 0 : 0 3 : 2 0 0 : 0 4 : 5 0 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 10 - 1 6 2 7 # L i n e a r S p a c e r a n d D a r t D r o p 2 0 1 , 2 6 0 3 0 3 0 0 : 0 1 : 3 0 0 : 0 1 : 3 0 1 . 0 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0 . 1 5 11 - 1 2 7 # L i n e a r P r e - P a d 2 0 2 , 1 0 0 5 0 5 0 0 : 0 2 : 3 0 1 : 0 2 : 1 4 1 . 0 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 11 - 2 2 7 # D e l t a F r a c E s t a b l i s h S t a b l e F l u i d 2 0 8 , 4 0 0 2 0 0 2 0 0 0 : 1 0 : 0 0 0 : 5 9 : 4 4 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 11 - 3 2 7 # D e l t a F r a c P a d 2 0 5 , 1 6 5 1 2 3 1 2 3 0 : 0 6 : 0 9 0 : 4 9 : 4 4 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 11 - 4 2 7 # D e l t a F r a c C o n d i t i o n i n g P a d 1 6 / 2 0 C e r a m i c 0 . 5 0 2 0 6 , 0 0 0 1 4 3 1 4 6 3 , 0 0 0 0 : 0 7 : 1 8 0 : 4 3 : 3 5 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 11 - 5 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 2 . 0 0 2 0 2 , 0 0 0 4 8 5 2 4 , 0 0 0 0 : 0 2 : 3 6 0 : 3 6 : 1 6 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 11 - 6 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 4 . 0 0 2 0 3 , 2 0 0 7 6 9 0 1 2 , 8 0 0 0 : 0 4 : 3 0 0 : 3 3 : 4 1 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 11 - 7 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 6 . 0 0 2 0 3 , 1 0 0 7 4 9 4 1 8 , 6 0 0 0 : 0 4 : 4 2 0 : 2 9 : 1 0 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 11 - 8 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 7 . 0 0 2 0 4 , 8 0 0 1 1 4 1 5 0 3 3 , 6 0 0 0 : 0 7 : 3 2 0 : 2 4 : 2 8 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 11 - 9 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 8 . 0 0 2 0 4 , 3 5 0 1 0 4 1 4 1 3 4 , 8 0 0 0 : 0 7 : 0 4 0 : 1 6 : 5 6 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 11 - 1 0 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 9 . 0 0 2 0 3 , 0 0 0 7 1 1 0 0 2 7 , 0 0 0 0 : 0 5 : 0 2 0 : 0 9 : 5 2 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 11 - 1 1 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 1 0 . 0 0 2 0 1 , 9 2 0 4 6 6 6 1 9 , 2 0 0 0 : 0 3 : 2 0 0 : 0 4 : 5 0 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 11 - 1 2 2 7 # L i n e a r S p a c e r a n d D a r t D r o p 2 0 1 , 2 6 0 3 0 3 0 0 : 0 1 : 3 0 0 : 0 1 : 3 0 1 . 0 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0 . 1 5 12 - 1 2 7 # L i n e a r P r e - P a d 2 0 2 , 1 0 0 5 0 5 0 0 : 0 2 : 3 0 1 : 0 2 : 1 4 1 . 0 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0 . 1 5 Interval 9 Coyote @ 8958 - 8962 ft 104.5 °F Interval 10 Coyote @ 8460 - 8464 ft 104.5 °F Interval 11 Coyote @ 7962 - 7966 ft 104.5 °F Interval Coyote @ 10451 - 10455 Interval 7 Coyote @ 9954 - 9958 ft 104.6 °F Interval 8 Coyote @ 9456 - 9460 ft 104.5 °F Co n o c o P h i l l i p s - 3 T - 7 3 1 Pl a n n e d D e s i g n 2 CU S T O M E R Co n o c o P h i l l i p s FA L S E AP I BF D (l b / g a l ) 8. 5 4 LA T 70 . 4 1 9 9 1 8 7 4 LE A S E 3T - 7 3 1 L 2 SA L E S O R D E R BH S T (° F ) 10 5 LO N G -1 5 0 . 2 6 9 2 2 5 6 FO R M A T I O N Co y o t e DA T E M a x P r e s s u r e ( p s i ) 85 0 0 *E x c e e d s 8 0 % o f b u r s t p r e s s u r e * Pr o p S l u r r y D e s i g n C l e a n D e s i g n C l e a n D e s i g n S l u r r y D e s i g n P r o p S t a g e I n t e r v a l B C - 1 4 0 X 2 L o s u r f - 3 0 0 D M O - 6 7 C A T - 3 L D - 6 4 5 0 W G - 3 6 O P T I F L O - I I BE - 6 Tr e a t m e n t St a g e F l u i d S t a g e P r o p p a n t C o n c R a t e V o l u m e V o l u m e V o l u m e T o t a l T i m e T i m e Cr o s s l i n k e r S u r f a c t a n t B u f f e r C a t a l y s t C l a y C o n t r o l In t e r v a l N u m b e r D e s c r i p t i o n D e s c r i p t i o n D e s c r i p t i o n (p p g ) ( b p m ) ( g a l ) ( b b l ) ( b b l ) ( l b s ) ( h h : m m : s s ) ( h h : m m : s s ) (g p t ) ( g p t ) ( g p t ) ( g p t ) ( g p t ) ( p p t ) ( p p t ) ( p p t ) Li q u i d A d d i t i v e s Dr y A d d i t i v e s 50 - 1 0 3 - 2 0 9 0 5 - 0 1 12 - 2 2 7 # D e l t a F r a c E s t a b l i s h S t a b l e F l u i d 2 0 8 , 4 0 0 2 0 0 2 0 0 0 : 1 0 : 0 0 0 : 5 9 : 4 4 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0 . 1 5 12 - 3 2 7 # D e l t a F r a c P a d 2 0 5 , 1 6 5 1 2 3 1 2 3 0 : 0 6 : 0 9 0 : 4 9 : 4 4 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 12 - 4 2 7 # D e l t a F r a c C o n d i t i o n i n g P a d 1 6 / 2 0 C e r a m i c 0 . 5 0 2 0 6 , 0 0 0 1 4 3 1 4 6 3 , 0 0 0 0 : 0 7 : 1 8 0 : 4 3 : 3 5 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 12 - 5 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 2 . 0 0 2 0 2 , 0 0 0 4 8 5 2 4 , 0 0 0 0 : 0 2 : 3 6 0 : 3 6 : 1 6 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 12 - 6 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 4 . 0 0 2 0 3 , 2 0 0 7 6 9 0 1 2 , 8 0 0 0 : 0 4 : 3 0 0 : 3 3 : 4 1 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 12 - 7 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 6 . 0 0 2 0 3 , 1 0 0 7 4 9 4 1 8 , 6 0 0 0 : 0 4 : 4 2 0 : 2 9 : 1 0 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 12 - 8 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 7 . 0 0 2 0 4 , 8 0 0 1 1 4 1 5 0 3 3 , 6 0 0 0 : 0 7 : 3 2 0 : 2 4 : 2 8 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 12 - 9 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 8 . 0 0 2 0 4 , 3 5 0 1 0 4 1 4 1 3 4 , 8 0 0 0 : 0 7 : 0 4 0 : 1 6 : 5 6 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 12 - 1 0 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 9 . 0 0 2 0 3 , 0 0 0 7 1 1 0 0 2 7 , 0 0 0 0 : 0 5 : 0 2 0 : 0 9 : 5 2 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 12 - 1 1 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 1 0 . 0 0 2 0 1 , 9 2 0 4 6 6 6 1 9 , 2 0 0 0 : 0 3 : 2 0 0 : 0 4 : 5 0 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 12 - 1 2 2 7 # L i n e a r S p a c e r a n d D a r t D r o p 2 0 1 , 2 6 0 3 0 3 0 0 : 0 1 : 3 0 0 : 0 1 : 3 0 1 . 0 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0 . 1 5 13 - 1 2 7 # L i n e a r P r e - P a d 2 0 2 , 1 0 0 5 0 5 0 0 : 0 2 : 3 0 1 : 0 2 : 1 4 1 . 0 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 13 - 2 2 7 # D e l t a F r a c E s t a b l i s h S t a b l e F l u i d 2 0 8 , 4 0 0 2 0 0 2 0 0 0 : 1 0 : 0 0 0 : 5 9 : 4 4 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 13 - 3 2 7 # D e l t a F r a c P a d 2 0 5 , 1 6 5 1 2 3 1 2 3 0 : 0 6 : 0 9 0 : 4 9 : 4 4 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 13 - 4 2 7 # D e l t a F r a c C o n d i t i o n i n g P a d 1 6 / 2 0 C e r a m i c 0 . 5 0 2 0 6 , 0 0 0 1 4 3 1 4 6 3 , 0 0 0 0 : 0 7 : 1 8 0 : 4 3 : 3 5 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 13 - 5 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 2 . 0 0 2 0 2 , 0 0 0 4 8 5 2 4 , 0 0 0 0 : 0 2 : 3 6 0 : 3 6 : 1 6 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 13 - 6 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 4 . 0 0 2 0 3 , 2 0 0 7 6 9 0 1 2 , 8 0 0 0 : 0 4 : 3 0 0 : 3 3 : 4 1 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 13 - 7 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 6 . 0 0 2 0 3 , 1 0 0 7 4 9 4 1 8 , 6 0 0 0 : 0 4 : 4 2 0 : 2 9 : 1 0 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 13 - 8 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 7 . 0 0 2 0 4 , 8 0 0 1 1 4 1 5 0 3 3 , 6 0 0 0 : 0 7 : 3 2 0 : 2 4 : 2 8 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 13 - 9 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 8 . 0 0 2 0 4 , 3 5 0 1 0 4 1 4 1 3 4 , 8 0 0 0 : 0 7 : 0 4 0 : 1 6 : 5 6 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 13 - 1 0 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 9 . 0 0 2 0 3 , 0 0 0 7 1 1 0 0 2 7 , 0 0 0 0 : 0 5 : 0 2 0 : 0 9 : 5 2 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 13 - 1 1 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 1 0 . 0 0 2 0 1 , 9 2 0 4 6 6 6 1 9 , 2 0 0 0 : 0 3 : 2 0 0 : 0 4 : 5 0 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 13 - 1 2 2 7 # L i n e a r S p a c e r a n d D a r t D r o p 2 0 1 , 2 6 0 3 0 3 0 0 : 0 1 : 3 0 0 : 0 1 : 3 0 1 . 0 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0 . 1 5 14 - 1 2 7 # L i n e a r P r e - P a d 2 0 2 , 1 0 0 5 0 5 0 0 : 0 2 : 3 0 1 : 0 2 : 1 4 1 . 0 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 14 - 2 2 7 # D e l t a F r a c E s t a b l i s h S t a b l e F l u i d 2 0 8 , 4 0 0 2 0 0 2 0 0 0 : 1 0 : 0 0 0 : 5 9 : 4 4 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 14 - 3 2 7 # D e l t a F r a c P a d 2 0 5 , 1 6 5 1 2 3 1 2 3 0 : 0 6 : 0 9 0 : 4 9 : 4 4 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 14 - 4 2 7 # D e l t a F r a c C o n d i t i o n i n g P a d 1 6 / 2 0 C e r a m i c 0 . 5 0 2 0 6 , 0 0 0 1 4 3 1 4 6 3 , 0 0 0 0 : 0 7 : 1 8 0 : 4 3 : 3 5 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 14 - 5 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 2 . 0 0 2 0 2 , 0 0 0 4 8 5 2 4 , 0 0 0 0 : 0 2 : 3 6 0 : 3 6 : 1 6 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 14 - 6 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 4 . 0 0 2 0 3 , 2 0 0 7 6 9 0 1 2 , 8 0 0 0 : 0 4 : 3 0 0 : 3 3 : 4 1 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 14 - 7 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 6 . 0 0 2 0 3 , 1 0 0 7 4 9 4 1 8 , 6 0 0 0 : 0 4 : 4 2 0 : 2 9 : 1 0 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 14 - 8 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 7 . 0 0 2 0 4 , 8 0 0 1 1 4 1 5 0 3 3 , 6 0 0 0 : 0 7 : 3 2 0 : 2 4 : 2 8 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 14 - 9 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 8 . 0 0 2 0 4 , 3 5 0 1 0 4 1 4 1 3 4 , 8 0 0 0 : 0 7 : 0 4 0 : 1 6 : 5 6 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 14 - 1 0 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 9 . 0 0 2 0 3 , 0 0 0 7 1 1 0 0 2 7 , 0 0 0 0 : 0 5 : 0 2 0 : 0 9 : 5 2 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 14 - 1 1 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 1 0 . 0 0 2 0 1 , 9 2 0 4 6 6 6 1 9 , 2 0 0 0 : 0 3 : 2 0 0 : 0 4 : 5 0 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 14 - 1 2 2 7 # L i n e a r S p a c e r a n d D a r t D r o p 2 0 1 , 2 6 0 3 0 3 0 0 : 0 1 : 3 0 0 : 0 1 : 3 0 1 . 0 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0 . 1 5 15 - 1 2 7 # L i n e a r P r e - P a d 2 0 2 , 1 0 0 5 0 5 0 0 : 0 2 : 3 0 1 : 0 2 : 4 4 1 . 0 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 15 - 2 2 7 # D e l t a F r a c E s t a b l i s h S t a b l e F l u i d 2 0 8 , 4 0 0 2 0 0 2 0 0 0 : 1 0 : 0 0 1 : 0 0 : 1 4 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 15 - 3 2 7 # D e l t a F r a c P a d 2 0 5 , 1 6 5 1 2 3 1 2 3 0 : 0 6 : 0 9 0 : 5 0 : 1 4 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 15 - 4 2 7 # D e l t a F r a c C o n d i t i o n i n g P a d 1 6 / 2 0 C e r a m i c 0 . 5 0 2 0 6 , 0 0 0 1 4 3 1 4 6 3 , 0 0 0 0 : 0 7 : 1 8 0 : 4 4 : 0 5 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 15 - 5 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 2 . 0 0 2 0 2 , 0 0 0 4 8 5 2 4 , 0 0 0 0 : 0 2 : 3 6 0 : 3 6 : 4 6 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 15 - 6 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 4 . 0 0 2 0 3 , 2 0 0 7 6 9 0 1 2 , 8 0 0 0 : 0 4 : 3 0 0 : 3 4 : 1 1 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 15 - 7 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 6 . 0 0 2 0 3 , 1 0 0 7 4 9 4 1 8 , 6 0 0 0 : 0 4 : 4 2 0 : 2 9 : 4 0 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 15 - 8 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 7 . 0 0 2 0 4 , 8 0 0 1 1 4 1 5 0 3 3 , 6 0 0 0 : 0 7 : 3 2 0 : 2 4 : 5 8 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 15 - 9 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 8 . 0 0 2 0 4 , 3 5 0 1 0 4 1 4 1 3 4 , 8 0 0 0 : 0 7 : 0 4 0 : 1 7 : 2 6 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 15 - 1 0 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 9 . 0 0 2 0 3 , 0 0 0 7 1 1 0 0 2 7 , 0 0 0 0 : 0 5 : 0 2 0 : 1 0 : 2 2 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 15 - 1 1 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 1 0 . 0 0 2 0 1 , 9 2 0 4 6 6 6 1 9 , 2 0 0 0 : 0 3 : 2 0 0 : 0 5 : 2 0 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 15 - 1 2 2 7 # L i n e a r S p a c e r a n d D a r t D r o p 1 5 1 , 2 6 0 3 0 3 0 0 : 0 2 : 0 0 0 : 0 2 : 0 0 1 . 0 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0 . 1 5 16 - 1 2 7 # L i n e a r P r e - P a d 2 0 2 , 1 0 0 5 0 5 0 0 : 0 2 : 3 0 1 : 1 0 : 5 4 1 . 0 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 16 - 2 2 7 # D e l t a F r a c E s t a b l i s h S t a b l e F l u i d 2 0 8 , 4 0 0 2 0 0 2 0 0 0 : 1 0 : 0 0 1 : 0 8 : 2 4 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 16 - 3 2 7 # D e l t a F r a c P a d 2 0 5 , 1 6 5 1 2 3 1 2 3 0 : 0 6 : 0 9 0 : 5 8 : 2 4 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 16 - 4 2 7 # D e l t a F r a c C o n d i t i o n i n g P a d 1 6 / 2 0 C e r a m i c 0 . 5 0 2 0 6 , 0 0 0 1 4 3 1 4 6 3 , 0 0 0 0 : 0 7 : 1 8 0 : 5 2 : 1 5 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 16 - 5 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 2 . 0 0 2 0 2 , 0 0 0 4 8 5 2 4 , 0 0 0 0 : 0 2 : 3 6 0 : 4 4 : 5 6 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 16 - 6 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 4 . 0 0 2 0 3 , 2 0 0 7 6 9 0 1 2 , 8 0 0 0 : 0 4 : 3 0 0 : 4 2 : 2 1 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 16 - 7 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 6 . 0 0 2 0 3 , 1 0 0 7 4 9 4 1 8 , 6 0 0 0 : 0 4 : 4 2 0 : 3 7 : 5 0 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 16 - 8 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 7 . 0 0 2 0 4 , 8 0 0 1 1 4 1 5 0 3 3 , 6 0 0 0 : 0 7 : 3 2 0 : 3 3 : 0 8 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 16 - 9 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 8 . 0 0 2 0 4 , 3 5 0 1 0 4 1 4 1 3 4 , 8 0 0 0 : 0 7 : 0 4 0 : 2 5 : 3 6 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 16 - 1 0 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 9 . 0 0 2 0 3 , 0 0 0 7 1 1 0 0 2 7 , 0 0 0 0 : 0 5 : 0 2 0 : 1 8 : 3 2 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 16 - 1 1 2 7 # D e l t a F r a c P r o p p a n t L a d e n F l u i d 1 6 / 2 0 C e r a m i c 1 0 . 0 0 2 0 1 , 9 2 0 4 6 6 6 1 9 , 2 0 0 0 : 0 3 : 2 0 0 : 1 3 : 3 0 0 . 4 5 1 . 0 0 0 . 5 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 16 - 1 2 2 7 # L i n e a r F l u s h 2 0 3 , 5 0 0 8 3 8 3 0 : 0 4 : 1 0 0 : 1 0 : 1 0 1 . 0 0 2 . 0 0 1 . 0 0 2 7 . 0 0 2 . 0 0 0. 1 5 16 - 1 3 F r e e z e P r o t e c t F r e e z e P r o t e c t 5 1 , 2 6 0 3 0 3 0 0 : 0 6 : 0 0 0 : 0 6 : 0 0 16 - 1 4 S h u t - I n S h u t - I n 98 4 , 8 1 6 2 3 , 4 4 8 2 7 , 1 6 3 3 , 4 9 8 , 0 0 0 De s i g n T o t a l (g a l ) De s i g n T o t a l (l b s ) BC - 1 4 0 X 2 L o s u r f - 3 0 0 D M O - 6 7 C A T - 3 L D - 6 4 5 0 W G - 3 6 O P T I F L O - I I B E - 6 90 5 , 7 7 5 3, 4 9 8 , 0 0 0 (g a l ) ( g a l ) ( g a l ) ( g a l ) ( g a l ) ( l b s ) ( l b s ) ( l b s ) 72 , 2 6 1 In i t i a l D e s i g n M a t e r i a l V o l u m e 4 0 7 . 6 9 7 8 . 0 4 5 2 . 9 1 , 9 5 6 . 1 9 7 8 . 0 2 6 , 4 0 7 . 0 1 , 9 5 6 . 1 1 4 6 . 7 - 6, 7 8 0 - Wh o l e U n i t s t o b e o r d e r e d - - BC - 1 4 0 X 2 L o s u r f - 3 0 0 D M O - 6 7 C A T - 3 L D - 6 4 5 0 W G - 3 6 O P T I F L O - I I B E - 6 - (g p m ) ( g p m ) ( g p m ) ( g p m ) ( g p m ) p p m p p m p p m - Ma x A d d i t i v e R a t e 0 . 4 0 . 8 0 . 4 1 . 7 0 . 8 2 2 . 7 1 . 7 0 . 1 - Mi n A d d i t i v e R a t e 23 : 2 3 : 0 7 Interval 12 Coyote @ 7465 - 7469 ft 104.5 °F Interval 13 Coyote @ 6969 - 6973 ft 104.4 °F Interval 14 Coyote @ 6471 - 6475 ft 104.4 °F Interval 15 Coyote @ 5973 - 5977 ft 104.4 °F Interval 16 Coyote @ 5475 - 5479 ft 104.4 °F Pr o p p a n t T y p e 16 / 2 0 C e r a m i c 10 0 M -- - Fl u i d T y p e 27 # D e l t a F r a c 27 # L i n e a r Se a w a t e r Fr e e z e P r o t e c t --- - Co n o c o P h i l l i p s - 3 T - 7 3 1 Pl a n n e d D e s i g n 3 SECTION 13 – POST-FRACTURE WELLBORE CLEANUP AND FLUID RECOVERY PLAN 20 AAC 25.283(a)(13) After the fracture stimulation, ConocoPhillips (“CPAI”) plans to flowback the well for cleanup purposes for an estimated 7 to 14 days. The flowback liquids will be routed through a portable test separator then onto either CPF3 or Drill Site 3T’s facilities. Once the well’s flowback liquids meet CPF3 criteria all liquids will be routed to CPF3. CPAI plans to limit the flowback time to what is necessary to achieve conforming production liquids.