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Home My WebLink About2015 Nicolai CreekAurora Gas, LLC May 24, 2016 k h t ' t'- ` 100,,) Ms. Cathy P. Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7t' 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 2015 at Nicolai Creek Unit No. 1 B, 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 10-412 Reservoir Pressure Reports for Nicolai Creek -South Undesignated for 2015; 3) Form 10-412 Reservoir Pressure Reports for Nicolai Creek -Beluga for 2015; 4) Nicolai Creek Unit Pressure Map, showing pressures for 2015; and 5) Supporting information: P/Z vs. Cumulative Production Plots for #113, #2, #9 (3), and #11 (3). If you have any questions or require additional information, please contact me at (281) 495-9957 by email at j&11C. d aaur�ra u�� cr.com. . Sincerely, AURORA GAS, L J. Edward Jones President enclosures cc: Temple Davidson and Kevin Pike, ADNR-DOG 1// p "/ 4645 Sweetwater Blvd., Suite 200 • Sugar Land, Texas 77479 • (281) 495-9957 • Fax (832) 999-4382 1400 West Benson Blvd., Suite 410 • Anchorage, Alaska 99503 • (907) 277-1003 • Fax (907) 277-1006 NICOLAI CREEK UNIT WELLS NO. 1 B, 29 9, and 11 RESERVOIR SURVEILLANCE REPORT RE: CONSERVATION ORDER NO. 478A HISTORYAND SUMMARY AS OF 12/31/15 A; 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 2015. The well has produced a total of 2707.8 MMcf (2.7 BCF) thru 12/31/15, of which 596.6 MMcf is allocated to the Lower Completion, 1830.5 MMcf to the Middle Completion, and 280.7 MMcf to the Upper Completion. NOTE: All three of the above well are on the same pad, with the #113 and 42 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. Thus, at year end, the Upper Middle and Lower Middle (both Beluga) completions were 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 1196.5 MMcf through 12/31/2015: 321.6 MMcf allocated to the Upper Middle Completion, 548.9 MMcf allocated to the Lower Middle (Beluga) Completion and 326.1 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. 1 B, 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: #113-1625 prig 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: #113-1211 psig at -2537' TVDss (commingled currently open perfs of Carya 2-2.1 to the 2-3 at 24801- 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 psia (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 2015, showing annual reservoir pressures, along with some comments. Surface pressures have been used exclusively for annual pressures after initial pressures in Wells #2 and 49, which have made very little water, so they are consistently in single-phase condition. Surface pressures in #1B and #11 may be affected by some minor buildup of water in the wellbore, but no bottom -hole pressures were obtained in 2015. Note that due to the recompletions of 41B 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 10-412 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 536 MMcf from commingled from all the perfs, of which 458 MMcf were produced thru 12/31/15. The NCU #2 is shown to have an EUR of 996 MMcf, from the original Aurora Gas completion and new Upper Tyonek and Beluga commingled perfs, of which 932 MMcf had produced thru 12/31/15. The Middle Completion of the NCU #9 is given an EUR of 2194 MMcf, of which 1831 MMcf had produced thru 12/31/15—this interval is now commingled with the Lower Completion, which is shown to have an EUR of 628 MMcf, of which 597 MMcf were produced thru 12/31/15, and with the Upper Completion, with an EUR of 311 MMcf of which 281 MMcf have produced. The commingled Lower (Tyonek) and Lower Middle (Beluga) completions in the NCU 911 are shown to have an EUR of 976 MMcf by the P/Z plot, of which 870.5 MMcf were produced thru 12/31/15. The Upper Middle Completion in #I I has an EUR of 686 MMcf of which 326 MMcf has produced thru 12/31/15. The recompletion of the NCU #113 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 #1 B, 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 I 1 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 43 and #10 upstream of the sales meter. It is 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 20 MMcf in 2015. It was producing about 30 mcfpd in December 2015. No additional work is planned in this well, except to put on booster compression, when manifolding work is done. NCU #2—This well produced 48.2 MMcf in 2015, with all but Lower Completion open and commingled—it produced 92 mcfpd in December 2015. 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. This well produced 88.8 MMcf in 2015. It averaged about 499 mcfpd in December 2015. 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 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 2015 came from the Lower (Tyonek) completion, with the Lower Middle completion providing production in December and possibly earlier. This well produced 85.8 MMcf in 2015, averaging only 47 mcfpd in December 2015 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 #1B, #2, and #11 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 (5/23/16) d� E a � ry O O m) _ N N N M d � n o S r E n d m V E e n d °1 mom, u l m N ij N N ¢ y m N Q N r (n ti m E m E a U) o. � w r x d m o LU 0 w w W E a cn w y O Z W LL g v Z ui E H r N a N a o O R E K m Zi WU E O - Q ) E d @ ;n E a m U) O ° o Z 16 J M O °a li t 20w 0 0 U � � n tj O W n '� O N UJ O n Ti u F R <Jq Y W a a 0 0 0 a o Q o m m o d m m m (p m d Qj O � Qi m m N d v U a d v 5 m L n r y m d d o ad 00 Q J n O d w Zap yb ¢ O N m u vti m o m € N UJ O dd E i o o q a c o M y c o �', ` 0 2 `p Z 41 m v � v d N m d E w W F N O Z Z N O Z N O Z L d E Z Z a a= m m r m E W d a m Z u rc E a u g v Z # a 00 O w E n 3 U U a v L ¢ /, 01.- _ / ME _i ]0 \!_ : - 0w..) { / { / \ \ } \ \ \ \ ■ < � :( \§2 {` {; LU A 0 ) - \_IL - m)■- _ \ \ \ /|§§ \ \ \ ow - - . - - \ j \ \ \ \ UJ j \ \ \ < \ \ \ \& \ \ \ \ \ \ \\ '6 _ : !! (kD /(/) \/ \ \ \ \ \ \ \ \ \ \ \ o \ k \ - _\/\\j \� #I I Beluga DATUM -1913' TVDSS INITIAL -- 905 psig 12/2015- 238 psig SEC 30 NCU #11 411 Tyonek DAIUM -2295' TVDSS INITIAL - 914 psig 3/15- 294 psig NICOLAI CREEK FIELD SOUTH Undesignated & BELUGA POOLS (SOUTH, WEST, & BELUGA PA's) NCU 1 / DATUM -2537'TVDSS INITIAL — 1211 psig 6/15— 202 psig NCU 6 DATUM -1527 TVD INITIAL — 663 psig 8/2015 — 280 psig SEC 29 BELUGA-TYONEK DATUM -1937' TVDSS INITIAL - 1025 psig 11/15 - 311 psig TYONEK DATUM - -2766' TVDSS INITIAL - 959 psig 11/15 - 299 psig i kill, NCU SOUTH PA 1. Aurora Gas, LLC NCU 4 FIELD. NICOLA[ CREEK COUNTY STATE: KENAI PENINSULA BOR., ALASKA RESERVOIR COMMINGLED CARYA 2-1 TO 2-5.1 (Perls at Wichert-Aziz correction for contaminants, if any 2,000 1,800 1,600 1,400 1,200 m H 1,000 a x In 800 600 400 200 0 0 85.0 0.56 2,801 N 338.00 Kyder Newt r1 Reservoir Solutions 6.0 (Public) /Pmf¢cfarll 100 200 300 400 500 600 Cumulative Production, MMcf POINT NUMBER (Automatic) DATE (Optional) SITP, Psia BHP, Psia s LSMF Data BHP2, Psia CUM PROD, MMcf LSMF Include? (Y/N) 1 2 3 ' o Excluded Data -- 1,107 611 0.8489 0.8832 0.93101 --- J` aEUR=536 1 •OGIP=565 � n _ Y Y 4 6/12/2007 _ _ _ 535 568 0.9355 607 159 Y 5 9/12/2007 438 0.9497 461 226 Y 6 5@912008 345 366 0.9577 382 261 n 7 5/21/2009 _ 328 348 0.9598 362 282 C 8 10/15/2010 535 568 0.9355 607 290 100 200 300 400 500 600 Cumulative Production, MMcf POINT NUMBER (Automatic) DATE (Optional) SITP, Psia BHP, Psia z BHP2, Psia CUM PROD, MMcf LSMF Include? (Y/N) 1 2 3 12115/2003 6/6/2006 2/10/2007 1,490 1,036 575 1,107 611 0.8489 0.8832 0.93101 1,877 1,253 656 0 0 95 n _ Y Y 4 6/12/2007 _ _ _ 535 568 0.9355 607 159 Y 5 9/12/2007 438 0.9497 461 226 Y 6 5@912008 345 366 0.9577 382 261 n 7 5/21/2009 _ 328 348 0.9598 362 282 n 8 10/15/2010 535 568 0.9355 607 290 y 9 2/4/2011 375 398 _ _ 0.9542 417, 320 Y 10 10/1/2011 365 387 _ _ 0.9553 _ 405 328 Y 11 10/31/2012 285 _ _ 302 0.9649 313 373 y 12 1/21/2013 320 339 0.9607 353 381 y 13 8/11/2013 360 _ 382 0.9559 399 386 _ Y 14 12/13/2014 225 238 0.9722 245 437 Y 15 6/3/2015 205 217 0.9746 223 450 Y These results were prepared with Ryder Scott's Gas Material Balance . This is not Ryder Scott work product. FIELD: NICOLAI CREEK GAS FIELD COUNTY, STATE: KENAI PENINSULA BOR., ALASKA RESERVOIR: COMMINGLED UPPER TYONEK +BELL Wichert-Aziz correction for contaminants, if any WELLHEAD TEMP, °F: 45.0 1 SOUR GAS MOL 1,400 1,200 1,000 m 800 .y a a m 600 400 200 0 0 Ryder Scott r.t--r Reservoir BHP, Psia Solutions 6.0 (� (Public) — -- 1 --- 11/21/2003 200 400 600 800 1,000 1,200 Cumulative Production, MMcf 98 POINTNUMBER (Automatic) DATE (Optional) SITP, Psia BHP, Psia 4 LSMF Data BHP/Z, Psia CUM PROD, MMct LSMF Include? (Y/N) -- 1 --- 11/21/2003 - ----- 0.8712 ----1,231'' i oExcluded Data _ Y 2 2 111=20n;; 11/22/2003 1 1,004 rEUR=9961 i i ! 0.8725 1,215 2 Y � ♦OGIP=1,095 j f 1 2/11/2004 766 807 0.8997 897 142 Y 4 7/15/2004 p 626 ♦ 680 270 I 5 7/16/2005 ♦ 436 0.9440 F 472 Y ' 1 300 F 200 400 600 800 1,000 1,200 Cumulative Production, MMcf 98 POINTNUMBER (Automatic) DATE (Optional) SITP, Psia BHP, Psia Z BHP/Z, Psia CUM PROD, MMct LSMF Include? (Y/N) -- 1 --- 11/21/2003 1,016 1,073 0.8712 ----1,231'' - 0-- _ Y 2 2 111=20n;; 11/22/2003 1 1,004 1,060 0.8725 1,215 2 Y 3 1 2/11/2004 766 807 0.8997 897 142 Y 4 7/15/2004 595 626 0.9208 680 270 Y 5 7/16/2005 415 436 0.9440 462 472 Y 6 3/8/2007 300 315 0.9593 328 624 Y 7 _ 8/11/2007 287 301 0.9610 314 647 Y 8 9 10 11 12 13 _ 9/1/2009 11/30/2010 11/25/2011 10/31/2012 8/25/2014 11/14/2015 300 293 315 360 370 265 315 308 _ 331 378 389 299 0.9593 0.9602 0.9573 0.9513 0.9500 0.9613 328 320 346779 3987796 409 311 739 765 787 922 Y Y Y Y Y Y These results were prepared with Ryder Scott's Gas Materia/ Balance. This is not Ryder Scott work product. WELL NAME: NICOLAI CREEK UNIT #9 SOUR GAS Ryder Scott i•; FIELD: NICOLAI CREEK CUM PROD, MMcf Reservoir COUNTY STATE: KENAI PEN. BOR. (WEST SIDE OF COOK INLET), ALASKA CO, Solutions RESERVOIR: BELUGA (TSUGA 2-6) PERFS AT 1148-1264' (UPPER COMPL) HS (Public) Wishart -A717 eorracfion for contaminants. if anv ,Protected) WELLHEAD TEMP, "F: 40.0 SOUR GAS MOLE % BOTTOMHOLE TEMP, rF: 66.0N CUM PROD, MMcf 0.87 WET GAS GRAVITY: 0.562 CO, 0.33 TVD, FEET: 1,206 HS 0.00 wNU. eumtcr IYIN1: N Corrected• Tc, rR: 343.56 Corrected' Pc, Palo: 672.16 700 600 500 a 400 Least Squ tot BHP/z 200 100 p 0 50 100 150 200 250 300 350 400 Cumulative Production, MMcf POINT NUMBER (Automatic) DATE (Optional) SITP, Psia BHP, Psia Z BHP/Z, Psia CUM PROD, MMcf LSMF Include? (YIN) 1 2 9/15/2003 9/15/2006 5401 572 555 0.9224 0.9247 _ 620 6001 0 0 N Y 3 1/31/2013 235 241 0.9667 249 147 Y 4 8/25/2013 165 169 0.9766 173 201 n 5 6/12/2014 185 190 0.9738 195 245 y Point 1 is XPT These results were prepared using Ryder Soott's Gas Materia/ Balance. This is not Ryder Scott mrk product. FIELD: NICOLAI CREEK UNIT _ JNTY. STATE: KENAI PENINSULA BOR.. ALASKA Wichert-Aziz correction for contaminants, if anv WELLHEAD TEMP, "F: 40.0 1 SOUR GAS I MOLE % BOTTOMHOLE TEMP, `F: 66.0 NZ 0.89 WET GAS GRAVITY: 0.563 CO, 0.00 TVD, FEET: 1,364 HS 0.00 (.UNU. t;VKKr (T/N): N Corrected` Tc, °R: 344.83 Corrected' Pc, Psia: 672.05 800 ) 700 600 500 m N 400 a x m 300 200 100 0 0 xyder scoa :+7 Reservoir-�J Solutions 6.0 , (Public) 500 $1 1,000 1,500 2,000 2,500 Cumulative Production, MMcf POINT NUMBER (Automatic) DATE (Optional) SITP, Psia BHP, Psia LSMF Data BHP/Z, Psia CUM PROD, MMcf LSMF Include? (Y/N) 1 2 3 4 Excluded Data j 667! 5861 515 677 688 605 531+ 0.9077 0.9062 0.9171 0.9268 746 760 659 573 j tEUR=2,194 Y--- Y Y Y 5 12/31/2004 405 A OGIP = 2,365 e ij 443 666 N 6 fj 420 433 0.9400 461 660 Y 7 7/1612005 435 4481 0.9379 478 t Y 8 2/1711006 325 3351 0.9534 351 864 O � 9 9/12/2006 173 178 O 183 1,068 N 10 5/21/2009 O 227 0.9683 234 1,228 N ___ 11 500 $1 1,000 1,500 2,000 2,500 Cumulative Production, MMcf POINT NUMBER (Automatic) DATE (Optional) SITP, Psia BHP, Psia Z BHP/Z, Psia CUM PROD, MMcf LSMF Include? (Y/N) 1 2 3 4 9/22/2003 11/20/2003 2/11/2004 6/18/2004 667! 5861 515 677 688 605 531+ 0.9077 0.9062 0.9171 0.9268 746 760 659 573 -- 0 0 108 310 Y--- Y Y Y 5 12/31/2004 405 417 0.9421 443 666 N 6 4/30/2005 420 433 0.9400 461 660 Y 7 7/1612005 435 4481 0.9379 478 682 Y 8 2/1711006 325 3351 0.9534 351 864 Y 9 9/12/2006 173 178 0.9751 183 1,068 N 10 5/21/2009 220 227 0.9683 234 1,228 N ___ 11 9/2/2009 255 263 0.9633 273 1,228 Y 12 7/4/2010 235 242 0.9662 251 1,392 Y 13 9/21/2010 2051 211 0.9705 218 1,453 _ Y 14 818/2011 1841 189 0.9735 195 1,532 Y 15 8/27/2012 110 113 0.9641 115 1,697 N 16 1131/2013 _ 195 201 _ _ 0.9719 207 1,697 Y 17 8/25/2013 165 170 0.9762 174 1,744 N 18 6/12/2014 185 191 0.97331 196 1,779 Y 19 1/7/2015 195 201 0.9719 207 1,795 Y 20 8/29/2015 275 283 0.9605 295 1,795 Y These results were prepared with Ryder Scott's Gas Material Balance. This is not Ryder Scott work product. ELL NAME: NICOLAI CREEK UNIT #9 1 SOUR GAS Ryder Scott FIELD: NICOLAI CREEK NZ Reservoir ? ; TY, STATE: KENAI PEN. BOR., (WEST SIDE OF COOK INLET), ALASKA CO2 Solutions °SERVOIR: BELUGA (TSUGA 2-7 & 2-8) PERFS AT 1552-1904 (LOWER) 1 HIS (Public) enrroefinn fnr mea faminants. if am (Protected) WELLHEAD TEMP, "F: 40.0 1 SOUR GAS MOLE % IS MHOLE TEMP, rF: 74.0 NZ 0.87 WET GAS GRAVITY: 0.562 CO2 0.33 TVD, FEET: 1,728 1 HIS 0.00 CorGOND. GORR7 (Y/N): N rected' Tc, °R: 343.56 Corrected' Pc, Pula: 672.16 1,000 900 800 700 600 A y a H 500 a 400 300 61N11 100 0 100 200 300 400 500 600 700 800 Cumulative Production, MMcf POINT NUMBER (Automatic) DATE (Optional) I SITP, Psia BHP, Psia Z BHPIZ, Psia CUM PROD, MMCf LSMF Indude? (YIN) 1 9/2612006 650 676 0.9139 739 2 y 2 2/10/2007 4351 452 0.9414 480 94 n 3 511/2007 505 525 0.9323 563 109 n 4 7/16/2007 475 493 0.9362 527 159 y 5 8111/2007 637 0.9186 693 163 n 6 9125/2003 810 0.8981 902 0 n 7 8/11/2007 389 404 0.9475 426 163 n 8 11/6/2007 385 400 0.9480 422 208 n 9 5/2912008 351 365 0.9525 383 271 Y 10 10/13/2008 260 270 0.9647 280 325 Y 11 517/2009 215 223 0.9707 230 385 n 12 5/21!2009 2201 228 0.9701 235 385 n 13 9/2/2009 255 265 96 0.53 274 385 Y 14 7/4/2010 235 244 0.9680 252 413 Y 15 9/21/2010 205 213 0.9721 219 434 Y 16 8/8/2011 184 191 0.9749 196 460 Y 17 8/27/2012 110 114 0.9850 116 535 Y 18 1/31/2013 195 202 0.9734 208 535 y 19 8125/2013 165 171 0.9775 175 545 n 20 6112/2014 185 192 0.9748 197 5561 Y These results were prepared using Ryder Scott's Gas Material Balance. This is not Ryder Scott work product. WELL NAME: NICOLAI CREEK UNIT #11 J Ryder Scott }1—!„ FIELD: NICOLAI CREEK Reservoir a ,. J COUNTY, STATE: KENAI PENINSULA BOR., ALASKA (WEST SIDE COOK INLET) Solutions 5.0 RESERVOIR: L. Tsuga 2-7 (Perfs 1349-1675) Upper Middle Completion (Public) Wichu .Avis mmnMinn fnr ennfaminantn. if anv (Protected) WELLHEAD TEMP, °F: 50.0 1 SOUR GAS MOLE h BOTTOMHOLE TEMP, *F: 81.5 Ni 1.00 WET GAS GRAVITY: 0.562 CO= 0.00 TVD, FEET: 1,512 1 HS 0.00 Comm CORR7 (YIN): N Corrected" Te, °R: 344.25 Corrected' Pc, Psia: 671.89 800 700 600 500 Least tot rt, 100 0 0 100 200 300 400 500 600 700 800 Cumulative Production, MAAcf POINT NUMBER (Automatic) DATE (Optional) SITP, Psia I BHP, Psia Z I BHP/Z, Psia CUM PROD, I MMcf LSMF Include? (YIN) 1 2 9113/2009 9/24/2009 583 677 603 0.9174 0.9259 737 651 _ 0 _ 0 n Y 3 11/1/2012 315 325 0.9592 339 266 Y 4 8/22/2013 385 398 0.9504 418 322 y These results were prepared using Ryder Scott's Gas Material Balance. This is not Ryder Scott work product. FIELD: RESERVOIR: Lower 8 Lower Middle WiehnK_AA7 rnrmrtinn fnr rnntaminants- If anv Ryder Scott 1:1 Reservoir .L , CA _ Solutions 6.0 Carya 2-1 at 1736-2367) (Public) /Prnterledl WELLHEAD TEMP, °F: 50.0 1 SOUR GAS MOLE % BOTTOMHOLE TEMP, °F: 87.0 Nz 1.00 WET GAS GRAVITY: 0.562 1 COr 0.00 TVD, FEET: 2,049 HA 600 wnu. wefnz trrnl: n Corrected' Tc, °R: 344.25 Corrected' Pc, Psia: 671.89 1,200 q 1,000 R 800 n H 600 'a x m 400 200 0 0 nr1PMitfrF 1.130 200 400 600 800 Cumulative Production, MMcf 1,000 1,200 POINT NUMBERDATE (Automatic) (Optional) SITR Psia BHP, Psia • LSMF Data BHPfZ, Psia CUM PROD, MMd LSMF Include? (Y/N) 1 2 3 4 5 6 7 i c Excluded Data 881 585 595 433 315 385 340 923' _ 0.8946 6121 _ 0.9276 6221 0.9264 4521 0.9457 329 0.9602 402 0.9515 355 j 0.9571 1,032 659 672 478 342 422 371 — -- --- 0 282 293 533 631 697 721 DEUR=952 i \ 12/18/2015 235 245 j �OGIP=1,130 253 874 Y 40 ! 1 i _ I 200 400 600 800 Cumulative Production, MMcf 1,000 1,200 POINT NUMBERDATE (Automatic) (Optional) SITR Psia BHP, Psia Z BHPfZ, Psia CUM PROD, MMd LSMF Include? (Y/N) 1 2 3 4 5 6 7 10!6/2009 9/1/2010 10/11/2010 8/8/2011 10/31/2012 8/22/2013 8/27/2014 881 585 595 433 315 385 340 923' _ 0.8946 6121 _ 0.9276 6221 0.9264 4521 0.9457 329 0.9602 402 0.9515 355 j 0.9571 1,032 659 672 478 342 422 371 — -- --- 0 282 293 533 631 697 721 Y Y Y Y Y Y Y 8 12/18/2015 235 245 0.9701 253 874 Y These results were prepared with Ryder Scott's Gas Material Balance. This is not Ryder Scott work product. WELL NAME: NICOLAI CREEK UNIT #11 SOUR GAS ayes r Scott L j- FIELD: NICOLAI CREEK N; IV Reservoir COUNTY STATE: Kenai PB, AKSolutions - _ -- -- -- 6.0, RESERVOIR: Carya 2 8-1.1 22-1.2 (perta s t 2260-2362') H2S (Public) Wichert-Aziz correction for contaminants. if amt (Protected) WELLHEAD TEMP, `F: 50.0 SOUR GAS MOLE % B_OTTOMHOLE TEMP, *F: 90.0 N; 1.00 WET GAS GRAVITY: 0.562 CO, 0.00 TVD, FEET: 2,311 H2S 0.00 GOND. GUKH7 (YIN): N Corrected` R: 344.25 Corrected' PC, Psta: 671.89 1,200 1,000 800 m a H 600 'a x m 400 200 0 50 100 150 200 250 300 350 400 450 Cumulative Production, MMcf POINT NUMBER (Automatic) DATE (Optional) SITP, Psia BHP, Psia Z BHP2, Psia CUM PROD, MMcf LSMF Include? (Y/N) 1 10/6/2009 881 928 0.8962 1,036— _- 0 Y 2 9/21/2009 950 0.8941 1,063 0 Y 3 10/11/2010 595 62fi 0.9275 __ 674 44 Y 4 8/8/201 1 43 3 455 0.9464 480 69 Y 5 10/31/2012 315 331 0.9607 344 154 n 6 8/22/2013 385 404 0.9522 424 230 Y 7 8/27/2014 340 357 0.9576 373 230 Y 8 3/31/2015 295 309 0.9631 321 283 Y 9 12/18/2015 235 246 .9705 0.9706r7 254 327 Y These results were prepared with Ryder Scott's Gas Material Balance This is not Ryder Scott work product.