Artificial Lift in Mature Fields Case Study of the Golfo San Jorge Basin Argentina

Transcription

1 ARTIFICIAL LIFT CONFERENCES February 2006 Jakarta,, Indonesia Artificial Lift in Mature Fields Case Study of the Golfo San Jorge Basin Argentina By Marcelo Hirschfeldt Patagonia Argentina

2 Outline Argentina Regional context - Oil & gas production history and distribution Golfo San Jorge Basin (GSJB) Introduction - Reservoir characteristics - Oil & water production trends GSJB - Artificial Lift Systems - Sucker rod / PCPump / ESPump & others - Artificial lift evolution Typical example Lifting cost consideration & evolution Conclusions

3 Argentina Regional context Argentina South America Buenos Aires GOLFO SAN JORGE BASIN

4 Argentina- Regional context General Information Five productive basins Oil [bpd]: 649,240 Gas [MMcfpd] 4,866 Water [M bpd]: 5,015 Water %: 90 Active Oil Wells: 18, bopd / well Active Gas Wells: 1,320

5 Basins Production distribution North-West Oil production - Mbpd 300 Cuyana % 43.4 % Neuquina G. San Jorge % 6 % 5.8 % Austral

6 Oil well distribution Cuyana 5 % Austral Noroeste 1.7 % 0.3 % Neuquina 30 % Golfo San Jorge 63 % Oil wells : 18,200

7 Argentina - Production History Oil & Gas Production History (average per year) 800 4,0 Cumulative oil Production Oil - M bopd ,070 MM BO 3,0 2,0 1,0 Gas - MM cfpd

8 Argentina Oil Production 6,000 1,200 5,000 1,000 4, Water - M bpd 3,000 2,000 1,000 Golfo San Jorge Oil - M bopd

9 Artificial Lift distribution PCP 10 % 1,824 Natural flowing 1.9 % 351 Gas lift 1 % 176 Plunger lift 0.8 % 141 ESP 15.3 % 2,787 SRP Total oil wells : 18, % 12,901

10 Golfo San Jorge Basin

11 Golfo San Jorge Basin (GSJB) Comodoro Rivadavia First oil well drilled in Comodoro Rivadavia in 1907 General Information Area [M Acre]: 28,000 Oil [bpd]: 281,500 Gas [MM cfpd]: 447 * Water [M bpd]: 2,686 Water %: 90 Active oil wells: 11, bopd / well API (Type Escalante) 24 Atlantic Ocean * All the water is injected 2005 RIG Count Drilling : 30 Wokovers: 65

12 145 miles Sarmiento 94 miles Comodoro Rivadavia Caleta Olivia Las Heras Cañadón Seco Pico Truncado Cities

13 Golfo San Jorge Basin (GSJB) Sarmiento Comodoro Rivadavia Caleta Olivia Las Heras Cañadón Seco Pico Truncado Cities Oil fields distribution

14 GSJB- Reservoir characteristics Enviroment of deposition Fluvial and alluvial braided stream. Reservoir rocks Sandstones Multi layers (lens) Since 30 Individual Reservoir in some wells Traps Tilted horst blocks, faulted anticlines, combination structural/stratigraphic stratigraphic Stratigraphic pinchouts

15 GSJB - Reservoir characteristics South North West East

16 GSJB - Reservoir characteristics South North 3,000 ft 10,000 ft 65 miles

17 GSJB - Oil and Water Production 3, , Water - M bpd 2,000 1,500 1, Oil - M bopd 500 Water Oil

18 Oil produced from Waterflooding 60% 50% 40% 30% 20% 10% 0% % of oil production is from secondary recovery (waterflooding)

19 Water % evolution 100% 98% 96% 94% Water - % 92% 90% 88% 86% 84% 82% 80%

20 Typical oilfield in Golfo San Jorge Finishing of primary stage (natural declination) and beginning of secondary recovery projects (water flooding) High fluid flow rate extraction (in 51/2 casing) High water % and oil production from secondary recovery Complex fluids: corrosive, heavy oil, gas, sand and scale Multitphaces fluids (Oil + gas + water) Multilayer reservoir (from 3000 to 9000 ft) in the same well

21 GSJB - Artificial Lift Overview

22 Artificial lift & typical well completion SRP - 78 % - 8,989 PCP - 11 % - 1,313 ESP - 10 % - 1,125 Gas Lift - Plunger Lift Jet pump 51/2 Casing (95 %) Vertical well Some directional wells

23 Artificial Lift Evolution 12,000 Number of wells 11,000 10,000 9,000 8, % 135 % 17 % Grows in the last 5 years 7,000 S.Rod pumping Beam Pumping ESP PCP

24 Sucker rod pumping

25 Sucker rod pumping Surface Conventional, MII & Air Balanced Max Torque: 1,280 [M in.lbs] Long- Stroke Pumping Units- 300 The bigest MII in Latin America Pump off controler Sucker rod Grade D: 1-7/81 7/8-3/4 Best practices & Innovations LUFKIN MII ROTAFLEX Sucker rod over size pin SR ¾ - 7/8 pin / SR 7/8 1 pin High Strength Rods & special alloy TENARIS-Siderca Pumps Insertable & Tubing pump : From 1 ½ to 3 ¼ diameter

26 Sucker rod pumping 12,000 10, bfpd Pulling Job /well / year: Pump depth - ft 8,000 6,000 4,000 2,000 5,400 ft 0 0 1,000 2,000 3,000 4,000 Flowrate fl - bfpd b d

27 Sucker rod pumping Flowrate - bfpd Pump depth- ft Flowrate 1,800 1,600 1,400 1,200 1, ,000 10,000 8,000 6,000 4,000 2,000 Summary Numb of wells : 8,989 Average flowrate - bpd: 400 Average pump depth - ft : 5,400 Pulling Job /well / year: ,000 2,000 3,000 4,000 5,000 6,000 7,000 8,000 Number of wells

28 Progressive Cavity Pump (PCP)

29 Progressive cavity pump Drive head Best practices & Innovations Direct & Right angle Max. power : 75 Hp Sucker rod string Grade D : 1 1 & 7/8 Hollow rods (PCP Rods ) High Strength Rods & special alloy TENARIS-Siderca Downhole Tubular & Insertable pumps Single lobe NBR & HNBR Elastomer High flow rate single lobe pumps : rpm Downhole pressure & temperature sensor

30 Progressive cavity pump 8,000 7,000 6, bfpd Pulling Job /well / year: Pump depth - ft 5,000 4,000 3,000 2,000 1, ,000 ft ,000 1,500 2,000 2,500 3,000 Flowrate - bfpd

31 Progressing cavity pump Pump depht - ft Flowrate - bfpd 2,000 1,500 1, ,000 7,000 6,000 5,000 4,000 3,000 2,000 1, ,000 1,200 Number of wells Summary Num of wells : 1,313 Average flowrate - bfpd: 770 Average pump depth - ft : 4,000 Pulling Job /well / year:

32 Electric submersible pump (ESP)

33 Electric submersible pump Surface Best practices & Innovations Switchboards Variable Speed Drive (VSD) Downhole 456 series 5 1/2 casing Instalation under deepest perforations (51/2 casing) Series Motors with refrigeration shrouds - Recirculation systems = = = = ESP Wood Group Recirculation Systems - CENTRILIFT

34 Electric submersible pump ,300 bfpd Pulling Job /well / year: Pump depth - ft ,500 ft Flowrate - bfpd

35 Electric submersible pump Pump depth - ft Flowrate - bfpd 4,000 3,000 2,000 1, ,000 8,000 6,000 4,000 2,000 Summary Num of wells : 1,313 Average flowrate - bfpd: 1,300 Average pump depth - ft : 6,500 Pulling Job /well / year: ,000 Number of wells

36 Other Artificial lift experiences Gas Lift Plunger Lift Hydraulic Jet Pump Cerro Dragon Oilfield- PanAmerican Energy Cerro Dragon Oilfield- PanAmerican Energy Diadema Oilfield - CAPSA

37 Artificial lift summary Pump depth - ft ESP PCP SRP Flowrate - bfpd

38 Artificial lift evolution - Example Example of artificial lift evolution before and during a waterflooding project Maximum reservoir depth= 7,000 ft 5 1/2 Casing We consider one oil well and one water injector well Waterflloding pattern Oil well Water injetion well

39 Artificial lift evolution - Example Primary One year Secondary recovery (waterflooding) 1000 Water injection bpd 100 Oil + water Oil 10 ESP SRP 1 Declination First stage Second stage Increase pump size & depth setting Change ALS for ESP Increase pumping speed & size Increase pumping speed, pumping units & pump size Small pumping unit & pump size

40 Lifting Cost

41 GSJB Lifting cost considerations Oilfields with more than 85 % of water & Oil from Waterflooding (60-80 %) Energy (15-30 %) Self generated Rental or bought Gas (owned or bought) ALS efficiency Flow rate x depth (HHP) Energy distribution 80 % for production 20 % Water injection Others Fluid treatment Personnel Others Surface maintenance (15-25 %) Type of contracts Operative model Major artificial lift sistems Sub-surface maintenance (25-35 %) Failure index Leas or contract for artificial lift supply

42 Lifting cost evolution Effect of system efficiency Lifting cost model solution Lifting cost u$s / B.O.E Cumulative production (% of Final Recovery) By John G. Svinos & Terry Treiberg Theta Enterprices, Inc SPE Forecast Techniques for Lifting Cost in Gas and Oil Onshore Fields- Ricardo E. Martínez nez-perez Companc

43 Conclusions What is our challenge? To increase the productive basin life How to achieve it? Waterflooding project (improving recovery factor) Deepest reservoirs Exploration Off shore development To continue improving our artificial lift experience

44 Contact information Marcelo Hirschfeldt Patagonia Argentina