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Home My WebLink About2016 Nicolai CreekAurora Gas, LLC May 11, 2017 RECEIVED Ms. Cathy P. Foerster, Chair MAY 15 2017 Alaska Oil and Gas Conservation Commission /'t�`l V �e 333 West 7"' Ave., Suite 100 Anchorage, Alaska 99501 RE: Reservoir Surveillance Report and Reservoir Pressure Reports (Form 10-412) Aurora Gas, LLC: Nicolai Creek -South Undesignated and -Beluga Dear Commissioner Foerster. Aurora Gas, LLC hereby submits a Reservoir Surveillance Report and four Reservoir Pressure Reports for the pressures taken in 2016 at Nicolai Creek Unit No. IB, No. 2, No. 9, and No. 11 gas production wells in the Nicolai Creek Gas Field on the west side of Cook Inlet, as required by Conservation Order No. 478A. Please find enclosed the following information for your files: 1) Reservoir Surveillance Report (Combined for NCU- South and NCU- Beluga) for 2015; 2) Form 101312 Reservoir Pressure Reports for Nicolai Creek -South Undesignated for 2016; 3) Form 10-412 Reservoir Pressure Reports for Nicolai Creek -Beluga for 2016; 4) Nicolai Creek Unit Pressure Map, showing pressures for 2016; and 5) Supporting information: P/Z vs. Cumulative Production Plots for #1B, #2, #9 (3), and #11 (2). If you have any questions or require additional information, please contact me at (281) 495-9957 by email at Sincerely, AURORA GAS, LLC J. Edward Jones President enclosures cc: Temple Davidson and Becky Kruse, ADNR-DOG 4645 Sweetwater Blvd., Suite 200 • Sugar Land, Texas 77479 • (281) 495.9957 • Fax (832) 999-4382 1400 West Benson Blvd,, Suite 00 • Anchorage, Alaska 99503 • (907) 277-1003 • Fax (907) 277-1006 NICOLAI CREEK UNIT WELLS NO. 1131 2, 9, and 11 RESERVOIR SURVEILLANCE REPORT RE: CONSERVATION ORDER NO. 478A HISTORYAND SUMMARY AS OF 12/31/16 BACKGROUND Aurora Gas, LLC re-entered and side-tracked the abandoned Texaco Nieolai Creek Unit (NCU) No. 1A in 2002 and completed the well in three Upper Tyonek sands, the Carya 2-4.2 at 3137-3157' TVD, the Carya 2-5.1 at 3307-3348' TVD, and the Carya 2-6.1 at 3506-3521' TVD. These intervals were commingled upon completion and tested with an AOF of 3.1 MMCfpd. Unfortunately, in spite of free -hanging sand control screens in the completion string, the well produced water and sand along with the gas, and, consequently, produced very little gas for sales to date. Unable to control the sand production by surface means, the well was recompleted in June of 2006: 1) plugging off the Carya 2-6 sand, from which the sand and much of the water was being produced (as evidenced by sand fill and a "sand -blasted" hole in the screen at that depth), 2) adding perforations to the Carya 2-3 sands at 2783-2864' TVD, the Carya 2-2.2 sands at 2550- 2568' TVD, the Carya 2-2.1 sands at 2426-2434' TVD, and the Carya 2-1.2 sands at 2254-2316' TVD, and 3) completing selectively (see attached well bore diagram). As of December 2006, the Carya 2-3 to the Carya 2-1.2 sands were mechanically open and producing (perfs at 2307-2918' MD), and the deeper sands, 2-4 to 2-5 (perfs at 3191- 3401' MD) were opened in October 2010 following a chemical sand control treatment. All these perfs are open have been producing since, with some sand possibly covering some of the lower perfs. However, the well has produced 468.8 MMcf through 12/31/16, most of which has come from the upper completions. The NCU No. 2 well was also re-entered by Aurora Gas in 2002 and re - completed into the Upper Tyonek Carya 2-1.1 sand at 2141-2177' TVD, the Carya 2-1.2 sand at 2342-2354', and the Carya 2-2.1 sand at 2493-2511' TVD. These commingled intervals tested for a calculated AOF potential of 14.6 MMcfpd. A production facility and gathering line were constructed in 2003 and the well started producing to sales December 2003. The well was recompleted in September- October of 2013 with a selective completion, going back to the original (Texaco) zone, the Carya 2-2.3 at 3268- 88' and 3324-36' MD and opening new zones, the Carya 2-1.0 at 2312-22' MD and the Lower Beluga at 2198-2212' and 2244-60'. The shallower two zones were commingled but not put on production until a Commingling -Spacing Order was approved in March 2014. The well has produced 958.9 MMcf since the re-entry thru 12/31/16. The NCU No. 9 was drilled on the same pad as the two directional wells above in 2003 to capture reserves behind two strings of pipe in the two old wells. It was completed in a Beluga Tsuga 2-7 interval at 1320-1447' TVD/MD (now the Middle Completion). This well tested yielding at calculated AOF potential of 49.1 MMcfpd. It also started producing to sales in December 2003. Because this completion had depleted significantly, a recompletion adding additional Tsuga 2-8, 2-7, and 2-6 sands from 1148- 1904' was completed in September 2006. The well produced 326 MMcf from the Lower Completion at 1552-1904' (9 different Tsuga 2-7 and 2-8 sands) between the recompletion in October 2006 and October 2008. In October 2008, the pressure of this Lower Completion had declined to near that of the Middle Completion, so the sliding sleeves for the Middle Completion were opened, allowing both the Middle and Lower Completions to produce commingled. In August 2012, these two lower producing intervals were closed off, and the Upper Completion, Beluga Tsuga 2-6, was opened to production. On January 31, 2013, al zones were opened to commingle production as pressures were nearly equalized, and this commingled flow continued for all of 2016. The well has produced a total of 2843 MMcf (2.8 BCF) thru 12/31/16 of which 629 MMcf is allocated to the Lower Completion, 1921 MMcf to the Middle Completion, and 292 MMcf to the Upper Completion. NOTE: All three of the above well are on the same pad, with the #113 and #2 being directional, so all have the same ground level elevation (22' AMSL) and nearly the same KB/DF elevation, so TVD's are very nearly TVDss and, thus, almost directly correlative. NCU #11—The Nicolai Creek Unit #11 well was drilled in September 2009 to a depth of 3600' (MD/TVD) and was completed on October 6, 2009, in 14 Beluga sands and 2 Upper Tyonek sands isolated by packers and sliding sleeves into 4 selective completions. The well was tested in the commingled completions in the Beluga Lower Tsuga 2-7 and 2-8 interval from 1736-2099' TVD and in the Upper Tyonek Carya 2-1 interval at 2260- 2362'. These commingled intervals were tested (4 -point) to give an CAOF of 5466 mcfpd with a static pressure of 924 psia (909 psig) at a datum of 2049' TVD (-2033' TVD SS). Production was initiated from the Tyonek Carya 2-1 completion in December 2009, and the well produced 11,281 mcf that month. Following commingling approval, the well produced from the Beluga and Tyonek perfs at 1736-2362', sometimes selectively, sometimes commingled. Two shallower selective completions were briefly tested upon completion and are thought to be productive, but were not produced until the Upper Middle Completion (Beluga Tsuga 2-6 with perfs between 1349- and 1675') was opened in September 2011—it produced until January 2014, when a tubing patch was placed across the sliding sleeve for that completion, which was believed to be leaking and the source of at least some of the sand fill. The Upper Completion, Beluga Tsuga 2-5 and 2-6 with perfs at 920-1216', was tested in early 2013 and found to produced water with sand, so it has not produced to sales. The Lower Middle Completion has produced most of the time since being opened, sometimes commingled production with the Lower (Tyonek) Completion—it alone produced from January 2014 until August 2014. The Lower Completion seemed to make sand (which may actually have been coming from Upper Middle Completion above), and fill has been cleaned out with coiled tubing three times, in June of 2011, in 2013, and again on 8/27/14, after which it was put on stream with the other Completions closed in. This continued for most of 2015; however, in December, fill was found above the Lower Completion, plugging it off, the sleeve to the Lower Middle Completion was found to be open, and the tubing patch across the leaking sliding sleeve for the Upper Middle Completion was pulled. Since then, the Upper Middle and Lower Middle (both Beluga) completions have been open and producing, while the Lower Completion is plugged off by fill until cleaned out. The production when commingled is allocated back to each zone on the basis of production tests when each zone is producing by itself. The well produced 1244 MMcf through 12/31/2016: 336 MMcf allocated to the Upper Middle Completion, 583 MMcf allocated to the Lower Middle (Beluga) Completion and 326 MMcf allocated to the Lower (Tyonek) Completion. CONSERVATION ORDER NO. 478A REQUIREMENTS This Order issued October 16, 2003, by the AOGCC has three items pertaining to reservoir surveillance at Nicolai Creek Unit wells No. 1B, No. 2, and No.9, requiring: 1) (0) Initial reservoir pressures, 2) (#4) Annual monitoring of reservoir pressures, and 3) (#5) Annual reservoir surveillance reports. INITIAL RESERVOIR PRESSURES Form 10-412's for both Pools (Nicolai Creek—South undesignated and Nicolai Creek—Beluga) for 2002 and 2003, show initial reservoir pressures. The initial reservoir pressures for #1B and #2 were obtained by bottom -hole pressure surveys (No. 1B and 2) and confirmed by quartz -crystal surface pressures extrapolated to subsea datum. These initial pressures were: # 1 B-1625 psig at -3293' TVDss, and #2-1025 psig at -2285' TVDss. The #9 well was taken by quartz -crystal surface pressure recorder and was confirmed by open -hole MDT measurements—it was 673 psig at -1348' TVDss. Subsequent work, i.e., the 2006 recompletions of #1B and #9, added the following original pressures: #1B-1211 prig at -2537' TVDss (commingled currently open perfs of Carya 2-2.1 to the 2-3 at 2480'- 2918' MD) and in #9-666 psig at -1706' TVDss (Lower Completion). The drilling of the #11 well in 2009 gave additional pressure information: it was tested in the commingled completions in the Beluga Lower Tsuga 2-7 and 2-8 interval from 1736-2099' TVD and in the Upper Tyonek Carya 2-1 interval at 2260-2362' with a static pressure of 924 psis (909 psig) at a datum of 2049' TVD (-2033' TVD SS). ANNUAL MONITORING OF RESERVOIR PRESSURES Attached are Form 10-412's for both Pools (Nicolai Creek—South undesignated and Nicolai Creek—Beluga) for 2016, showing annual reservoir pressures, along with some comments. Surface pressures have been used exclusively for annual pressures after initial pressures in Wells #2 and #9, which have made very little water, so they are consistently in single-phase condition. Surface pressures in #IB and #11 may be affected by some minor buildup of water in the wellbore, but no bottom -hole pressures were obtained in 2016. Note that due to the recompletions of #I B and #9 in 2006 and the subsequent production of different intervals, the datum TVDss's for these wells have changed since the 2006 submittals. Note also that the #11 well is included in these 10412 reports although it is in a different PA (West)—the Lower Middle (Beluga) completion is included in the Beluga Pool report and the Lower (Tyonek) Completion is included with the South Undesignated Pool. The reservoir pressure survey data and production data from the four producing wells have been plotted to yield P/Z vs. Cumulative Production curves, providing a material - balance projection of reserves. Those plots (using Ryder Scott Excel templates) are attached—there are eight. These show the NCU #1B having an EUR of 539 MMcf from commingled from all the perfs, of which 469 MMcf were produced thru 12/31/16. The NCU #2 is shown to have an EUR of 1048 MMcf, from the original Aurora Gas completion and new Upper Tyonek and Beluga commingled perfs, of which 959 MMcf had produced thru 12/31/16. The Middle Completion of the NCU #9 is given an EUR of 2249 MMcf, of which 1920 MMcf had produced thru 12/31/16—this interval is now commingled with the Lower Completion, which is shown to have an EUR of 639 MMcf, of which 629 MMcf were produced thru 12/31/16, and, until 9/28/16 when the Upper sleeves were closed, with the Upper Completion, with an EUR of 341 MMcf of which 294 MMcf have produced. The Lower (Tyonek) perfs have been plugged with fill since late 2015, so no production or pressures have been obtained from that interval in 2016. The Lower Middle (Beluga) completion in the NCU #11, which is shown to have an EUR of 639 MMcf by the P/Z plot, of which 583 MMcf were produced thru 12/31/16, is commingled with the Upper Middle Completion, which has an EUR of 499 MMcf of which 336 MMcf has produced thru 12/31/16. The recompletion of the NCU #1 B in June 2006 provided additional pressure information of some of the Upper Tyonek Carya sands that have been producing in the #2 well. This pressure data from the tests indicates that there is no depletion of these zones in the No. 1B from the No. 2 production. In particular, the Carya 2-1.1, 2-1.2, and 2-2.1 are commingled in the #2 and had an initial SIBHP at -2285' TVDss of 1025 psig. The comparable zones in the #1B, commingled 2-2.1 and 2-2.2 and the 2-1.2 had bottom -hole SIP's estimated at 1045 and 1040 psig at datum of -2484' and -2272' TVDss, both are close to the original pressure in #2 and much higher than the then most recent SIBHP's of 293 psig at -2285'. This indicates that there is a geological barrier and no communication between the two well bores. POOL PRODUCTION ALLOCATION FACTORS The production from NCU 1B, 2, 9, and 11 is metered several times and allocated back to each well on the basis of these meters. Each of the wells has an individual separator into which the well flows, eliminating any free water from the flow stream, then immediately downstream of the separators, each well is individually metered. The flow from the wells may be combined at this point and then compressed before going thru the glycol dehydration system. (Booster compression has been added, so the lower pressured wells can be selectively compressed before going to the main compressor). After dehydration, the combined flow from these wells is metered again before going into the gathering system. The gathering system takes the gas to the CIGGS Meter 6103/8103 where it is joined by the flow from NCU #3 and #10 upstream of the sales meter. Itis metered before being commingled into flow going into the formerly Marathon -operated CIGGS pipeline system, now Hilcorp Harvest KBPL. The total sales volume through this sales meter is allocated back to each well proportionally based on the individual well meter volume divided by the sum of all the wells meters' volumes minus lease -use gas, where lease -use (fuel) gas is allocated proportionately to each well at a facility. RESERVOIR DEVELOPMENT AND DEPLETION PLANS NCU 1B—This deeper intervals in this well were treated with the Weatherford chemical "Sand Aid" in 2011, and the Upper completions (Carya 2-1 thru 2-3) were treated with Sand Aid in October of 2012. These treatments seemed to remedy the sand production, reduced the water production, but may have hurt gas production. The well produced 11 MMcf in 2016. It was producing about 30 mcfpd in late 2016. No additional work is planned in this well, except to put on booster compression, when manifolding work is done. NCU #2—This well produced 21 MMcf in 2016, with all but Lower Completion open and commingled—it produced 20-30 mcfpd in in late 2016, being operated about 10 days per month. Because of the dry, limited reservoir, this well is a candidate for conversion to storage, should that option be pursued. NCU #9—This well is producing from the commingled Upper, Lower, and Middle completions since early 2013 when all the sliding sleeve were opened. However, in September, the Upper completion sleeves were closed in an attempt to reduce water/fines production. This well produced 135 MMcf in 2016. It averaged about 260 mcfpd in December 2016. Following the 2006 recompletion workover, this well bore still has 8 potential Beluga Tsuga 2-5 and 2-6 sands between 668' and 1054' that have apparent gas production potential. These sands were not completed at the time of the 2006 recompletion workover for 2 reasons: 1) the large pressure differential expected between these shallow sands and the deeper ones, and 2) the cement bond log indicates a top of cement at 840', so remedial cementing will be required for the shallower sand completions. Thus, at least one more recompletion workover is expected in the life of this well bore. This wellbore is also being considered for gas storage (Middle Completion, which is a high-quality reservoir) and would give an additional 2-2.5 BCF capacity to a storage project. NCU #11—This well has 4 completions, which were be opened selectively and produced as needed to meet market demand. However, the Upper Completion produced sand and water when opened in January 2013. The Upper Middle Completion, however, was opened in September 2011 and has produced through April 2013, when the Lower (Tyonek) Completion was cleaned out The Lower Completion produces some sand with small volumes of water and was cleaned out with coiled tubing in 2011, early 2012, April 2013, and August 2014. In 2013, a tubing leak was found, allowing the Upper Middle completion to be producing (and believed to be the source of much of the sand fill) -a tubing patch was run across it in early 2014 and pulled in December 2015. Most of the production in 2016 came from the Lower Middle completion, with the Upper Middle completion providing some production. This well produced 48 MMcf in 2016, averaging about 120 mcfpd in December 2016 with Lower Completion plugged off with sand --a coiled tubing cleanout is needed to restore it (Lower Completion) to production. Depending upon market demand and storage development, a shallow development well may be drilled to recover the shallower reserves in the #9 well, both those in the Upper Completion and the shallower undeveloped sands. This would facilitate the use of the very good quality Middle Completion reservoirs for storage and would eliminate the need for an expensive recompletion workover to access the shallowest reserves. Beyond the above mentioned development, no additional development of either Pool is anticipated, as the Pools (and PA's) are now outlined. RESERVOIR PRESSURE MAP AT DATUM Because each well had its individual reservoirs, a reservoir pressure map at datum seems to be irrelevant. However, now that there are some common sands open in the #I B, #2, and #I I it may have more relevance, although the sands are apparently not continuous between wells. Attached is a pressure maps of the Nicolai Creek --South Undesignated Pool and the Nicolai Creek—Beluga Pool, showing initial and current pressures at the several pertinent subsea Data. Ed Jones (5/9/17) a_N O V K 4N_ d E `o _HT » ,\ _ }!�� ) ) \ ) L §; ! \ (e _ \ � / / : owl, .. /\ 3 w ¥�: }�\�k iCL / - - )\■w!!! - \\k \\\\~ w /a ( \ 2 } m(D \ 2 - / In } o LU \ UJ \ } \ \ } \ \ \ \ / \ \ }2 (§ `• !) IF 2 !,!$ ;| ° k\ } �{ {{| O `< �E \\\((` j } j \{ NICOLAI CREEK FIELD SOUTH Undesignated & BELUGA POOLS (SOUTH, WEST, & BELUGA PA's) N SEC 30 SEC 29 r NCU #11 I .tel`. .. `... NCU 1 A cul N 2 NCU 4 NCU 5 Aurora Gas, LLC 2,000 1,800 1,600 1,400 1,200 m w a H 1.000 6 2 n 800 600 400 200 - -- DATE (Optional) SITP, Psia I BHP, Psia LSMF Ewdu EUR OGIF Z -- CUM PROD. MMcf - --' 12/15Y1003 602006 2/10/2007 6/1212007 1,490 1,038 -__575 535 1,594 — 1,107 611 - 568 0.8469 0.8832 0.9310 0.9355 _._ 7 1.877 1,253 656 607 01 0 95 1591 I 5 9/1212007438 0.9497 461 226 i 6 529/2008 7 _ 366 0.9577 382 I n Data — ded Data = 539 _ 568 0 0 100 200 300 400 500 600 Cumulative Production, MMcf POINT NUMBER (Automatic) DATE (Optional) SITP, Psia I BHP, Psia Z BHP/Z, Ps ia CUM PROD. MMcf I LSMF Include? (YIN) 1 2 3 4 12/15Y1003 602006 2/10/2007 6/1212007 1,490 1,038 -__575 535 1,594 — 1,107 611 - 568 0.8469 0.8832 0.9310 0.9355 _._ 7 1.877 1,253 656 607 01 0 95 1591 n Y Y Y 5 9/1212007438 0.9497 461 226 Y 6 529/2008 345 _ 366 0.9577 382 —...— 281 n 7 5/212009 328 _ 348 0.9598 362 282 n 8 10/152010 535 568 0.9355 607 290 y _ 9 2/4/2011 375 398 0.9542 417 320 Y 10 11 10/12011 10/312012 365 285 387_ _ 302 _ __0.9553 0.9649 _ _ 405 313 328 373 Y- y 12 12 1/2013 320 _ 339 0.9607 353 381 IF 13 8/11/2013 360 382 0.9559 3991 386 Y 14 12/132014 225 238 0.9722 245 437 Y 15 613/2015 205 217 0.9746 223 450 Y 16 12/8/2016 183 194 0.9773 1981 Y These results were prepared with Ryder Scott's Gas Materia/ Balance. This is not Ryder Scott work product. correction for contaminants. if am WELLHEAD TEMP.' 45.0_ SOUR GAS I MOLEX BOTTOMHOLE TEMP,'F: 78.0 N t 1.06 WET GAS GRAVITY: 0.5607 1 CO= 0.00 TVD, FEET: 2,309 HS 0.00 IiVOY. YVnRrtr)nt: N _ Corcectmr To, •R: 343.7 C 0 orrected` Pe, Psia: 671.82 1,400 1,200 1,000 m 800 y a a m 600 --- 400 --- - - 200 0 0 myaer xott — Reservoir .� Solutions 6.0 (Public} 1 200 400 600 800 1,000 1,200 1,400 CumuW&e Production, MMcf POINT NUMBER (Automatic) DATE (Optional) SITP, Psia I BHP, Psia Z i LSMF Data Excluded DSU —. CUM PROD, MMB LSMF Include? (YM) +-EUR = 1,055 1 'OGIP=1,160 1.0-16F_-_-- - 1,073 0.8712__ 1,237 0 Y 2 3 i i 1,060 ---807 0.8725 1,215 897 2 - -142 Y Y 4 7/152004 595 _ 626 __0.8997 0.9208 680 270 Y 5 7/16/2005 415 436 462 472 Y _ 6 3/812007 200 400 600 800 1,000 1,200 1,400 CumuW&e Production, MMcf POINT NUMBER (Automatic) DATE (Optional) SITP, Psia I BHP, Psia Z BHP2. Psia CUM PROD, MMB LSMF Include? (YM) 1 11121/2003 1.0-16F_-_-- - 1,073 0.8712__ 1,237 0 Y 2 3 11/22!2003 2/1112004 1,004 766 1,060 ---807 0.8725 1,215 897 2 - -142 Y Y 4 7/152004 595 _ 626 __0.8997 0.9208 680 270 Y 5 7/16/2005 415 436 462 472 Y _ 6 3/812007 300 315 _0.9440 0.9593 _ 328 624 Y 7 8/11/2007 287 -- 301 0.9610 ---- 314 647 Y 8 9/1/2009 3D0 —293-- 375 0.9593 328 739 Y 9 111302010 308 0.9602 320 765 Y 10 11 - 1212 11252011 1125- - 101312012 315 ---- 360 331 -- 378 0.9573 - -_ 0.9513_ 346 398 _ 779 -�- 787 Y Y_ 12 825_2014 _ 370 389 0.9500 409 796 Y 13 11/142015 285 299 0.9613 _ _ 311 -- 922 Y 14 12 2/5 016 _ 200 210 0.9727 216 95 8 Y -- 15 1/772017 345 362 - 0.9533 _ _ 380 _ 958 Y - These results were prepared with Ryder Scott's Gmt Material Balance. This is not Ryder Scott work product. 700 ISMF Data 600 Excluded Data EUR = 341 500 OGIP = 406 N 400 N a N a m 300 200 100 0 0 50 100 150 200 250 300 350 400 450 Cumulative Production, MMcf These results were prepared with Ryder Scott's Gas Malerial Balance- This is not Ryder Scott work product. 800 700 600 500 m N a N 400 a i m 300 200 100 LSMF Data Excluded Data EUR = 2,249 OGIP = 2,424 0 0 500 1,000 1,500 2,000 2.500 3,000 Cumulative Production, MMc1 POINT NUMBER (Automatic) DATE8HPlZ, (Optional} SfTP, Psi, BHP. P. Z Psia CUM PROD, MMd LSMF Include? (YIN) — 1 9/22/2003677 0.9077 746 _ 0 Y 3 11120/2003 2/1112004 667 586 _ 688 605 _ _ _ 0.9062 0.9171 760 -- 659 _ _ 0 108 _ Y Y 4 _6/1812004515 _ 531 0.9268 573 — 310 _ Y 5 12/3112004---405 417 0.9421 443 - _666 N 6 4/3012005 420 _ 0.9400 461 680 Y 7 _— 7/16/2005 435 _._ 448 0.9379 478 - - 662 -- Y 8 2/172006 __...... 32i--335--09534--351---- 864 Y 9 9112!2006_ 173 178 0.9751 183 _ 1,068 _ N 10 _ _ it 512112009 _91112009 220 255 227 263 0.9683 0.9633 234 273 _ 1,228 -- 1,228 N Y 12 13 — 7,1412010 — - _ 9/21/2010 235 205 242 211 0.9662 ---- 251 1,392 _ Y 0.9_7_(15 218 1,453 Y 14 &812011 184 189 0 9.735 _ 195 1,532 Y _ 15 8/27/2012 110 113 0.9841 115 1,697 _ N 16 1/31/2013 -------- 195 201 -- 0.9719 _ 207 1,697 Y _ 17 _ 8125/2013 165 _ 170 0.9762 - 174 1,744 _ N 18 _ _ --,---19 22 _ _611014 _ 102015 165 _ 195 .,, 191_----- 201 0.9733 0.9719 _ _ _ 196 207 1,779 1,795 _ Y Y 20 21 8129/2015 1218/2016 _ 275 195 283 201 0.9605 295 1,795 Y _ 0.9719 207 1,916 Y These results were prepared with Ryder Scott's Gas Material Balance. This is not Ryder Scott work product. 800 700 600 500 m N a H 400 a x m 300 200 100 LSMF Data Excluded Data EUR = 647 OGIP = 767 0 0 100 200 300 400 500 600 700 800 900 Cumulative Production, MMcf POINT NUMBER (Automatic) DATE (Optional) SITP, Psia BHP, Psia Z BHP2, Psia CUM PROD, MMd LSMF Indude? (YIN) 1 _ 2 _ 3 W6120D6 I _ 5/1/2107 7/1612007 650 505 475 _ _ 676 525 -- -493 _ 0.9130 0.9316 0.9356 _ 740 563 527 2 109 159_ Y Y Y 4 11!612007 385 351 400 364 0.9475 0.9520 422 383 208 271 _ Y _ Y _. 5!29/2008 _ 6 10/13/2008 260 270 0.9643 280 325 Y 7 922809--255 265 0.9650 --- 274 385 V- 8 822/1900 __ 235 244 0.9677 252 413 Y 9 921/2010 _ 205 213 0.9718 219 434 Y 10 11 -- SBI2011 827/2012 _ 184 110 .—_.. 191 114 0.9747 0.9848 196 116 _ 460 535 _ _ Y Y 12 736/122014 1/312013 196 203 0.9730 _ 209 535 _ 185 192 0.9745 197 555 Y 14 _ &292015 --W5------285--6.96-23----296---580- _I} Y __ 15 12820-16 195 _ 202 0.9732 __.___....._ 206 628 Y These results were prepared with Ryder Scott's Gas Material Balance. This is not Ryder Scolt work product _ -- I.— . _..,....,.,.,....1"...,.,,..,,_ _ Kyoerxout ••�. FIELD: --_.-_-_- -STAT- NtCOLAI CREEK_ Reservoir • COUNTY, -STATE: _ _ __ -Kenai PB, AK _ Solutions 6.0 ( � RESERVOIR: Upper Middle Completion-L. Tsuga 2-7 (Parts at 1349-1675) (Public) —� ` Wichert-Aziz correction for contaminants, if any WELLHEAD TEMP, OF; _ 50.0 SOUR GAS MOLE 16 Least Squares Mean Fit Results BOTTOMHOLE TEMP, °F: Nz 1.00 Y-Intercept, BHP/z 694 _ WET GAS GRAVITY: _81.5 0.562 _ C% 0.00 OGIP, MMCF 561 TVD, FEET: 1,51_2_-_ _ HS _ _ 0.00 COND. CORR7 (YIN): N EUR, MMCF 499 Corrected` Tc, "R: 344.25_ Recovery Factor 0.8888 Corrected` Pc, Psia:- 671.89 BHP1z @ Abandonment 77 800 700 - - LSMF Data _.. Excluded Data EUR = 499 600 :. _ OGIP=561 500 _ m 0 H 400 i al m 300 _ 200 100 0 0 100 200 300 400 500 600 Cumulative Production, MMcf POINT NUMBER DATE BHPIZ, CUM PROD, LSMF (Automatic) (Optional) SIiP, Psis BHP, Psia Z Psis Zc Include? (YIN) 1 I 9/13/2009 6770-9174 738' 0 Y 2 9/24/2009 583 603. 0.9259 651' 0 Y 3 --- - _ 11/1/2012 315 325- 0.9592 339' 266 Y 4 - - - - -- 8/22/2013 385 - 398 09504 418 322 Y 5 8/25/2016 175 - -- 181 09772 _-- 185 331 y These results were prepared with Ryder Scott's Gas Material Balance. This is not Ryder Scott work product 1,200 1,000 800 A 600N a a m 400 200 0 0 100 200 300 400 500 600 700 Cumulative Production, MMcf )ata W Data 339 708 800 POINT NUMBER (Automatic) DATE (Optional) I SITP, Psia BHP. Psia Z BHP/Z, Psia CUM PROD, MMcf LSMF Include? (Y/N) 1 ---- 2 3 - _ 10/612009 9/1/2010 _ 10/11/2010 881 585 ---- 595 920 610 620 089341 _0.9268 0.9256 1,030' _ __ _ 658 670 _ 0 ___ 264 276 Y Y Y 4 5 33112011 --f0_13-112012.-315--328 385 0.9510 422 - - - - 469 ---n 5 _401 365 401 __ _ 09598 0.9510_ 342 422 _ 430 - 491 Y - Y _ 6 8/22/2013 7 6M2/2014 275 -.- 286 6.9648 297 _ 519 _ Y 8 7/31/2016 _ 175 182 0.9775 186 567 Y 9 312012016 220 229 0.9717 236 541 Y 10 6125/2016 175 782 0.9775 186 558 -Y— These results were prepared vrith Ryder Scott's Gas Material Balance. This is not Ryder Scott work product.